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200-044
Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2000440 E-Set: 34718 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC 1 3 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑rr n tdown E]Performed: Suspend ❑ Perforate ❑ Other Stimulate LJ Alter Change Alter Casing Appro ed 'gram ❑ Plug for Redrill ❑'erforate New Pool ❑ Repair Well ERe-enter Susp Well ❑ Other: ❑ 2.Operator ConocoPhllllps Alaska, IDC. 4. Well Class Before Work: 5. Permit to Drill NumberNam: Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑� 200-044 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-22904-01-00 7. Property Designation (Lease Number): a. wen Name and Number ADL 25650 KRU 1 D -125A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5,639 feet Plugs measured None feet true vertical 4,051 feet Junk measured None feet Effective Depth measured 4,580 feet Packer measured 4529' feet true vertical 3,083 feet true vertical 3039' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 feet 16" 121' 121' PRODUCTION 4,689 feet 5-1/2" 4730' 3211' LINER 1,107 feet 3-1/2" 5637' 4049' Perforation depth: Measured depth: 5096-5410 feet True Vertical depth: 3552-3841 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 4,529' MD 3,039' TVD Packers and SSSV (type, measured and true vertical dept PACKER - SABL-3 Liner Tap Packer 4529' MD 3039' TVD SSSV-NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4501'-4560' MD, 3015-3064' TVD - Cement Plug 110'-4501' MD, 110'-3015' TVD - IA Cement Plug Treatment descriptions including volumes used and final pressure: 54 bbls 15.8 PPG Class G 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: WELL IS SHUT-IN Subsequent to operation: 14. Attachments (required per 20 AAC 25.070. 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development p ❑ Service Stratigraphic ❑ Copies of Logs and Surveys Run p] 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data❑ GSTOR ❑ WINJ ❑� WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-293 Authorized Name: Dusty Ward Contact Name: Dusty Ward contact Email: Dusty.Ward@conocophillips.com Authorized Title: Senior Wells Engineer r c/ Contact (907) 265-6531 Authorized Signature: ✓ �,.C.� Date: < ,'JGI I Phone: Form 30-404 Revised 4/2017 VTL JZ /"'//(7 IBM SLOAJDEC 132019 Submit Original Only �t /, (f7 KUP INJ WELLNAME 1D -125A WELLBORE 1D -125A Conoeo`PhillipsAQMO,�' Attributes Max Angle & MD TD WeIIGare AMAIN Wellboreidai Iclt°I MO (11KB ACI Btm t%KB) Agel RIC aeu I[mnoaor-o, ��.�� 11?1.,. I,....._�._ m.uso,tmvgoteew:m FM Last Tag onealacearketaddtll AnnahEon pegM1tflKB) Entl Data Wellbore Ged Money . Last Tag: SLM on TOC 4,060.0 1W122019 iD-125A fergusp FNNDER: z%+ _ Last Rev Reason Annodtpn End rude, W¢Ilbon Iasi Motl By REV REASON: MILL RETAINERICIBP/CEMENT t..... Via 1D -025A tipple, Easing Strings Casing pescrat on ED Rant CONDUCTOR 16 ID (in) Toputi set epth RKet 15.06 47.5 1210 see Depth nVDt... WULen(1 1611, 121.0 62.58 H40 Top Tm,atl WELDED TUBING PIIN& 1+fln cosinepeannpeion oDpn1 PRODUCTION -P09 5.56 Sidetrack Ip (int Top 1flKBt sat Depth tNlet 4.95 41.1 4,730.0 SN De pt' TO)_ End a. (I... Grese 3,211.0 15.50 L-80 TopThrcaa BTCM CONDUCTOR: 4rs.aLD Lasing Oescnptlon Optint WINDOW 512 ID tint Top tflNBf Seto piM1 (tIKBt 4.00 4,692.0 4,702.0 set oeptn ITIDt... Sudan Ra... Grave 3,1882 Top Thread TUBING 1PPI, 1.1 easing Lipper ipimn ED Rant LINER 312 ID (in) Tapeo l Set Depth tttK01 2.99 4,5297 5,636.5 set Depth LIVE) wvlen lL.. Gone 4,049.0 9.30 L-80 Tap Tbraait IBT-M00 Liner Details - - Top tflKD ToptNOt MEN) rvominallni Topincl t°t Ibm Oes Com (in) 4LvnMPlw: nppnKB 6,529) 3,0389 33 d6 PgCKEin EARED SABL-3 LINER TOP PACKER 2]80 Tubing Strings Tubes Description string Ma...mpn TopnlKED seroepth OJ'Ss'l epm(TVIR. wt Idem) band, Top Lonndcthe TUBING 31/2 2.99 28.1 6,529.] 3,0389 930 L -8D EUEBrtlMOD NeSUFT:4.4ppe Completion Details _ TOPIrvD) rop mal Nominal Top(nKB) (Fal 1•) It.-28ped coin ID fol :i .1 28.1 0.00 HANGER VETCO TUBING HANGER 3.500 i 4,4596 2,981.1 3533 INIPPLEICAMCO'IDS' LANDING NIPPLE 2.812 NIPPLE: 4459E 45044 7017.9 34.16 LOCATOR BAKER LOCATOR 2937 I 6 k 4,505.8 3,019.0 36.12 PSP BAKER'45-0O SPECIAL CLEARANCE PSR N/10' SEALS 2.985 4,5294 3,0383 3346 SEALASSY IMUDEL KBH-22' ANCHOR SEAL ASSEMBLY 2.985 Inge punch: 4,aJ1 D - - Other In Hole (INimline retrievable plugs, valves, pumps, fish, etc.) Top ITVD) Topmd LOCATOR'.4a46 Top (flleB) gIKB) f) Des Lam Runnette mpn) 110.0 110.0 0.01TUBINGCH PUNphase phase M Tubing of 5'X2"4 SPE CIR CH ,0deg 91142019 2992 PER: 4sns.3 726.0 7246 9.1] TUBING LEAK TUBING LEAK CONFIRMED BY EL-LOL 1125201 0.000 7 ',suAssr. 4SPI 4,501.0 3,015.1 34.25 TUBING PUNCH Perfor'eted Tubing wl EL 1.56"tbg punch 91412019 2.992 Y PATCH T SURFACE CSG PATCH down 3'11"Grum Etarterhead 5250009 Perforations & Slots nos wlNpowna.oszw,rack. PROWLTION -Prmi $INrtaca. a, "aaOU ToptRKB) Bim upot pens TopIE) Bim (ryD) (5noearyf (ttKB) gtKB) Lln[etl Zone Oate ) Type Co. 5,0960 5.130.0 3,552.3 3,5838 WSD, 1D -125A 5002000 4.0 WERE 180 DEG PH, 2.5"HCDP 5,160,0 5,194.0 3.611.5 3,642.9 WE B, 1D -12M 513012000 4.0 IPERF 180 DEG PH, 2.5"HC DP 5,210.0 5,234.0 3,fi9.6 3,6J9.7 AS Ad,i - 52012000 4.0 IPERF 180 DEG PH,2S"HC DP 12M IPERF: 50seakU 10� 5,2526 5,2600 3,696.2 3,]03.6 WS A3, ID - 5/302000 4.0 IPERF 180 DEG PH,25"HC DP 125A 500.0 5,288.0 3,7127 3,729.3 WE A3. 10- 5130/2000 4.0 IPERF 180 DEG PH, 2.5" HC DP 12M ment'aude Der.. 5,298.0 5,304.0 4 3,743.9 125A3, 1D- 51302000 40 3.738, 125-0 IPERF 180 DEG PH, 2.5' HC DP 5,3246 5,3380 3762.2 3,]]5.1 WS A2,1D- N3W2000 4.0 IPERF 180 DEG PH, 2.5' HC DP 125A IPERe5.2u)&S V 5360.0 5,365.0 3,786.1 3,799.8 WS A2, 1D- 513012000 41 WERE 180 DEG PH, 2.5" HC DP 125A 5.375.0 5384.0 3,801 3,8172 WS A2, 1D- 5129/2000 4.0 PERE 180 DEG PH, 2.5"HC DP IPERE: Se....Dp� 125A 5,396.0 5,4100 3,828.2 3.841.1 WE ,1p- 12912000 4.O IPERF 180 DEG PH, 2.5"HC DP PERF:S,SnpS..V 12M Gement Squeezes IPFA F: s,Zi9.05,sN.0�I Top MKS) "He mrcB I Top(rvD I Bum (nKB) I (rvo) (flRe) rues ..Do.. Co. 4,501.0 4,560.0 3,015.1 3,064.3 Tubing Cement 1002019 PUMPED ATOTAL OF 54 BBLS 158 PPG CIAS G Plug - DnllSd Out CEMENT. 53 BBLS THROUGH RETAINER AND 1 INTO IA THRU TUBING PUNCHES. LAID IN 1 BBL IPERF, 55x0-Skok 0 ION CEMENT TOP OF RETAINER. -(MILLED TUBING WITH 2.75"MILL)- ILL)"•-Notes: Notes;General 8 Safety (PERP, da.Dsedi End Dale Annotation 524/2009 NOTE: VIEW SCHEMATIC w/Alaska Scheousi IPERF: 50iea5 4/1112009 NOTE: 10-125 SIDETRACKED 411112000 NOTE: MONOBORE INJECTOR IPERP, S%ecEe MpD� LINER', d.SM7k NME 1 D-1 25A DTTMSTART JOBTYP SUMMARYOPS 08/18/19 DRILLING SUPPORT - EQUALIZED & PULLED 3 1/2 RBP @ 4555' RKB, TAG W/ GAUGES CAPITAL @ 4843' RKB MEASURED BHP @ SAME (1706 PSI), BRUSH n' FLUSH FROM 4570' RKB TO 4400' RKB, TAG @ 4843' RKB CTMD, JOB IN PROGRESS RECOVER THICK FLUID. 08/19/19 DRILLING SUPPORT - UNABLE TO DRIFT PAST 20'W/ 27'x 2.75" DUMMY DRIFT, DRIFT CAPITAL W/ 21'x 2.75" TOOLS BOBBLE PAST 20' TIGHT SPOT SIT DOWN MILL DOWN TO 4468' CTMD, ROP 24 FPH, JOB IN PROGRESS. @ 56' UNABLE TO PASS. JOB POSTPONED FOR NEW DRIFT'S. DRILLING SUPPORT - IN PROGRESS. 08/28/19 DRILLING SUPPORT - DRIFT FREELY w/ 2.4" OD x 31'-5" OAL DRIFT DOWN TO 4600' CAPITAL RKB. JOB COMPLETE & READY FOR PLAN FORWARD. 09/04/19 DRILLING SUPPORT - RUN 1 : SET PLUG @ 4560', CCL TO ME = 10.8', CCL STOP CAPITAL DEPTH = 4549.2'. DRIFT TBG W/ 2.79" GAUGE RING DOWN TO LTP @ 4529' RKB CMIT PASSED. LLR OF 0.33 BBL/MIN @ 2500 PSI THROUGH CAPITAL LEAK @ 726' RUN 2: PERFORATED TUBING @ 4501'- 4503', CCL TO TOP TBG W/ 25' OF 2.80" & 2.75" (BOTH UNABLE TO GET DEEPER SHOT = 87, CCL TO TOP SHOT = 4492.3' LLR ABLE TO ESTABISH 1 BBL/MIN @ 600 PSI AND 2 BBL/MIN @ 1400 PSI. 09/14/19 DRILLING SUPPORT - SHOOT 2.0" OD X 5 FT, 4 SPF, TUBING PUNCH FROM 110' TO CAPITAL 115' RKB. RAN 3-1/2 F-STOP HOLE FINDER TO 227' RKB. LRS PUMPED 5 BBLS DIESEL DOWN TBG TAKING RETURNS UP IA @ 1100 PSI @ 0.4 BPM FOR 5 BBLS. COMPLETE READY FOR CTU. 10/06/19 DRILLING SUPPORT - MIRU. RIH WITH DRIFT. TAG DB -10 PLUG AND FLAG COILED CAPITAL TUBING FOR DEPTH CONTROL. POOH. RIH AND SET CEMENT RETAINER AT 4481' RKB, PERFORM INJECTIVITY TEST AND WAIT ON CEMENT CREW. 10/07/19 DRILLING SUPPORT - WAIT ON CEMENT CREW. PUMP 10 BBLS OF 9.8# NaCl BRINE, CAPITAL 54 BBLS OF 15.8# CLASS G CEMENT FOLOWED BY 3 BBLS FRESH WATER AND 3 BBLS POWER -VIS CONTAINMENT AND DIESEL, PUMP 53 BBLS CEMENT THROUGH THE 2.75" FH -1 CEMENT RETAINER WHILE TAKING RETURNS UP THE IA, UNSTING AND LAY IN 1 BBL OF CEMENT ABOVE THE RETAINER FROM 4481' RKB TO 4366' RKB, CIRCULATE CONTAMINATE THROUGH TBG PUNCH AT 100' AT .25 BPM, WHEN AT SURFACE PUMP 3 BBLS NaCl DOWN THE TBG WHILE TAKING RETURNS UP THE IA, CHASE WITH 1 BBL DIESEL, ALLOW 72 HOURS BEFORE S/L TAG, JOB IN PROGRESS. 10/12/19 DRILLING SUPPORT - WITH 10'x 2.5" BAILER TAG TOC @ 4060' SLM. DRIFTED TBG W/ CAPITAL 2.78" DMY WRP TO TAG TOC & 4060' SLM (NO WEIGHT SWINGS OR OBSTRUCTIONS OBSERVED). READY FOR CBL. 10/15/19 DRILLING SUPPORT - RIG UP ELINE. LOG SCMT FROM 4050' TO SURFACE AT 30 FPM. CAPITAL LOG 24- ARM MULTIFINGER CALIPER FROM 4050' TO SURFACE AT 35 FPM. TAG TOC IN TBG AT 4090'. JOB COMPLETE. 10/19/19 DRILLING SUPPORT - RIH WITH 2.74" PDC BIT, TAG CMT AT 4060' CTMD, START CAPITAL MILLING AT 1.6 BPM ROP 22 FPH, MILLED DOWN TO 4300' CTMD, JOB IN PROGRESS 10/20/19 DRILLING SUPPORT - RIH WITH 2.74" 3 BLADE JUNK MILL, TAG CMT AT 4300' CTMD, CAPITAL MILL DOWN TO 4468' CTMD, ROP 24 FPH, JOB IN PROGRESS. 10/21/19 DRILLING SUPPORT - RIH WITH 2.75" 3 BLADE CONVEX PIRANHA MILL, TAG CMT AT CAPITAL 4468' CTMD, MILLED UP CMT AND DB -10 PLUG, DRIFTED TO 4630' RKB, FREEZE PROTECT WELL. READY FOR SLICKLINE, 10/24/19 DRILLING SUPPORT - DRIFT TBG W/ 2.79" GAUGE RING DOWN TO LTP @ 4529' RKB CAPITAL (ENCOUNTERED MULTIPLE TIGHT SPOTS); ATTEMPT TO DRIFT TBG W/ 25' OF 2.80" & 2.75" (BOTH UNABLE TO GET DEEPER THAN 104' RKB). DRIFT W/ 10' X 2.75" DOWN TO 4418' RKB. JOB COMPLETE & READY FOR PLAN FORWARD. Cement Detail Report 1 D-125 String: IA Cement Plug Job: DRILLING SUPPORT - CAPITAL, 8/18/201... Cement Details Description IA Cement Plug Cementing Start Date 1017/201 g 00:00 Cementing End Date Wellbore Name 1 D- bore Comment PUMPED A TOTAL OF 54 BBLS 15.8 PPG CLASS G CEMENT. 53 BBLS THROUGH RETAINER AND INTO IA THRU TUBING PUNCHES. LAID IN 1 BBL ION TOP OF RETAINER.'***'*(MILLED TUBING CEMENT WITH 2.75' MILL)****"**' Cement Stages Stage # <Stage Number?> Description IA Cement Plug Objective 1 Top Depth (ftKB) 110.0 Bottom Depth (ftKB) 4,501.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump but (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Methotl Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 15.8 PPG CLASS G, ***45 BBLS TO THE IA Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Tap (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (Wlsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 12/12/2019 D Co 21 K v o T 'o 0* @, 0 y -V O T o W W T = O n W O d -I m o lA n O m D c r o Borough: North Slope �. ymz to x 3 n lo' 3 m p ti 3: �. a o s a a • y n m fD 3 n N O D r ,� ,z 0 3 ' z Field: Kuparuk River ' ' • m n m 3 Q n W< T n r v a o e g g 'O o Location: 286' FNL & 599' FEL • • oa d • 3 wo Well: 1D -125A a Company: ConocoPhillips Alaska, Inc. r w E N --� G) Location: o=ff" o CTI O N 3 0o m D m oD v _ o 3 Co M N • � • a- o w c T d Z a n ii • M � o • Ill pZ n m (O N • W N fn W (fin W W O F W A A (n �J p O, d M C a i W • m m tNo o o lilt 0 (�O o m O T 3 m r 1 ._+ 0 3 n m o O ' • o r o s 2', d ' ca W x W N to m vii W W m O O o m~ F to Em N m (Q m m m o m o 0 o m n O y o< N o n v it 3 F j . . . (D v _ 0 o m o _ W S o o f p d m m 3 3 - o s d F 3 THE USE OF AND RELIANCE UPON THIS RECORDED -DATA BY THE HEREIN NAMED COMPANY (AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLOYEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SCHLUMBERGER AND THE COMPANY, INCLUDING: (a) RESTRICTIONS ON USE OF THE RECORDED - DATA; (b) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIONS REGARDING COMPANY'S USE AND RELIANCE UPON THE RECORDED -DATA; AND (c) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISION MADE IN CONNECTION WITH THE USE OF THIS RECORDED -DATA. 1. Header 10. 24 -Arm Caliper Log Repeat Pass Up @ 35FPM 2. Disclaimer 10.1 Integration Summary 3. Contents 10.2 Software Version 4. Remarks and Equipment Summary 10.3 Composite Summary 5. Depth Summary 10.4 Log ( PMIT Radii Log ) 6. Wellbore Schematic 10.5 Parameter Listing 7. Cement Evaluation Log Main Pass Up @ 30FPM 11. Calibration Report 7.1 Integration Summary 12. Tail 7.2 Software Version 7.3 Composite Summary 7.4 Log ( SCMT_VDL_Image ) 7.5 Parameter Listing 8. Cement Evaluation Log Repeat Pass Up @ 30FPM 8.1 Integration Summary 8.2 Software Version 8.3 Composite Summary 8.4 Log (SCMT_VDL_Image ) 8.5 Parameter Listing 9. 24 -Arm Caliper Log Main Pass Up @ 35FPM 9.1 Integration Summary 9.2 Software Version 9.3 Composite Summary 9.4 Log ( PMIT Radii Log ) 9.5 Parameter Listing Objective: Log SMCT and PMIT to determine top of cement for future possible cement job Correlated to Halliburton Tubing Punch Record dated 14 -Sep -2019. Tagged TOC in tubing @ 4090'. Offset TO not tagged. 40.85 SLB Crew: Collins, Reid, Drover, and Randrup. AFEA 0417690 / Activity Code: ZX14 39.28 SON: DWUJ-00138 Cement Evaluation Log: Remarks 24 -Arm Caliper Log: Remarks SCMT Centralized with CMIR above sonde, PMIT centralized with gemcos centered above integral centralizer below transmitter, and TTG and below fingers. Two knuckles above the below sonde. PMIT. Main Pass logged from 4050'to surface. Main Pass logged from 4050'to surface. Repeat pass logged over interval of 4050' to 37 Repeat pass logged over interval of 4050' to 3 All passes logged @ 0 PSI at 30FPM. All passes logged @ 0 PSI at 35FPM. PSTC Resolution = 0.1". Cement Evaluation Log: 24 -Arm Caliper Lo Toolstrin Toolstring P 9 9 Equip name Length MP name Offset MH -22 40.85 !i AH -38 39.28 p SAM -G 39.00 4Fl1I 120 EQF-43 37.68 11 PSTP-B:27 31.68 GR 27.97 67 PSTC 27.68 PS PSTC 0X0PSTC-TC-A:81 0l String 3 Bottom P8MS-B:27 Tempera 24.93 67 ture CQG Pre 24.58 /ssure _CCL 24.16 �PBMS 23.41 SCMT-CB: 23.41 8043 SEOi-CA SCMC- A: 8041 CMIR-AG SANS -03:8 043 SCMX-CA:B 041 AH -278 TTG{ —DT 14.32 Equip name Length MH -22 33.39 AH -38 31.82 SAH -G 31.54 EQF-43 .30.23 EQF-46 24.22 MP name Offset I ype UM I U-t3/A PSTP-B:2767 18.22 Serial Number 12.82 PSC-A GR 14.52 Calibration Date .<CBL5 DTSC 12.82 PSTC-A:813 PSTC 14.23 Calibrator Serial Number 265 PBMS-B:2767 PSTC Tool S 0.00 Number of Calibration Points —CBL3 11.82 tying Bottom Calibration Root Mean Square —MAP 11.32 Temperatur 11.47 Subsequent Trip To the Well Error 3 e IDW used as primary depth control. Calibration Peak Error —AUX 10.32 Prwsu 11.12 Logging Cable /CQG m /CCL 10.71 /PBMS 9.96 V ' AH-97[2] 9.90 AH-97[11 8.62 /SCMT 6.00 PMIT-A:766 7.29 �t MIiH MITC-A:728 MNS-A:766 FINGERS-29 Sr G D I Indinometer:76 CalipepIncli 3.06 6 no BNS-P �TOOL_ZERO 0.14 ,TOOL ZERO Lengths are in it Lengths are in ft Maxmum Outer Diameter = 1.688 in Mawm um Outer Diameter = 6.250 in Line: Sensor Locator, Value: Gating Offset Line: Sensor Location, Value: Gating Offset All measurements are relative to TDOL_ZERO Al measurements are relative to TOOL ZERO T IMINITUF Cement Evaluation Log 24-Arm Caliper Log Depth Measuring Device Type IDW-JA IDW-JA Serial Number 6633 6633 Calibration Date 05-Oct-2019 05-Oct-2019 Calibrator Serial Number 18 18 Calibration Cable Type 1-23ZA 1-23ZA Wheel Correction 1 -6.33 -6.33 Wheel Correction 2 -2.47 -2.47 Tension Device I ype UM I U-t3/A CMTD-B/A Serial Number 3017 3017 Calibration Date 04 -Oct -2019 04 -Oct -2019 Calibrator Serial Number 265 265 Number of Calibration Points 10 10 Calibration Root Mean Square Depth Control Remarks Log Sequence Subsequent Trip To the Well Error 3 3 IDW used as primary depth control. Calibration Peak Error 7 7 Logging Cable type 1-23ZA 1-23ZA Serial Number F114092 F114092 Length 18000.00 ft 18000.00 ft Conveyance Type Wireline Wireline Rig Type Rigless Rigless Cement Evaluation Log:Depth Control Parameters Depth Control Remarks Log Sequence Subsequent Trip To the Well All Schlumberger depth standards and guidelines followed. Reference Log Name HES Tubing Punch Record IDW used as primary depth control. Reference Log Run Number One Z -Chart used as secondary depth control. Reference Log Date 14 -Sep -2019 Subsequent Trip Down Log Correction 24 -Arm Caliper Log:Depth Control Parameters Depth Control Remarks Log Sequence Subsequent Trip To the Well All Schlumberger depth standards and guidelines followed. Reference Log Name HES Tubing Punch Record IDW used as primary depth control. Reference Log Run Number One Z -Chart used as secondary depth control, Reference Log Date 14 -Sep -2019 Subsequent Trip Down Log Correction KUP INJ WELLNAME 1D -125A WELLBORE ID -1255 ConocophillipS t _ WellAttributes Max Angle & MD TO i FmHow WBRateAANlWI WrIWe #iiae na19 MO¢MBj AEE 4iIKBI iasx:e. IrK;. c 94.57 z3s'r_a2 S�.a OS"aS iCNE ti2alpP'ni )zat4 t>tla� rna 04ta KaG4@I111 BfP BLNeatleb - Last Tag aM Oaptn iTunj. WYA.a111 .. Gadd TI veeaamz-pec: �:.c annct#1on 121.0 a.2,M M.40 N D2ptn lttNfll HM data .''ais.a Iaet Mad Ey .wce¢ n.�� t a¢t Bev Renenn PRODUCTION -Fos! s54 4n: 4t 4.730.0 - 413$$. !all -1201S --- Si1letxK UMN onwpt n OO ln) 0441 1twiftkal WCeDtn4ft"I <r r. 4..27S pc. '- 125:., :.- �l=,.. TaP{teCBI SkOWLi ittKBl aM Oaptn iTunj. WYA.a111 .. Gadd TI C.iNCUC'DR ie 47.5 `214 121.0 a.2,M M.40 N Can4g Oewtptton MIM1 IG,ni UP41M84 WOWth48KB1 i ). 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TiS ♦.9 (PERF 4.9 1PEPF .789r)E. —� i.3:8 S ... 4.9 IRSRF _ Cement Squ2eaes 5LzrI T✓1RIRK91 9bP IkKBI .Y.K91 'lfK6, (;nnd Rnnd ((;0R01 Cement Evaluation Log Main • 30FPM Acquisition System Version Maxwell 2019 9.0.106845.3100 Application Patch Wireline _NPD-ThruBit-2019.0_9.0.109638 Wireline _NPD -LEE -2019.0 9.0.111464 W ireline_NPD-W PP -2019.0_9.0.113184 Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[6]:Up Up 15.17 ft 4079.53 ft 15 -Oct -2019 15 -Oct -2019 ON -15.76 ft No Evaluation 11:37:05 AM 2:05:24 PM Log All depths are referenced to toolstring zero Company:ConocoPhillips Alaska, Inc. WeIIAD-125A —Cement Ev luation Loa, L 6 :U 0 Description: SCMT VDL Image format: Log (SCMT_VDL_Image) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Qct -201918:54:36 TIME 1900 - Time Marked every 60.00 (s) I CBL Amplitude (CBL) SCMT-CB 0------------------1- mv CBL Amplitude (CBL) SCMT-CB 0 mV 100 (;nnd Rnnd ((;0R01 0 mV 10j Gamma Ray (GR) PSTP-B Normalized Average MAP 0 gAPI 150 Amplitude (AVMA) SCMT-CB Relative Bearing (RB_SCMT) 0 mV 100 SCMT-CB --------------'------- 0 deg 360 Normalized Minimum MAP Amplitude (MIMA) SCMT-CB Transit Time for CBL (TT) 0 mV 100 SCMT-CB 200 us 400 Normalized Maximum MAP Min Amplitude Max Cable —Amplitude (MXMA) SCMT-CB P < N m CCL Computed Amplitude (CCLC) Tension 0 mV 100 PSTP-B (TENS) VDL VariableDensity (VDL) — - - - ' SCMT-CB CBL Amplitude Mapping Image (0 - -19 V 1 20001bf 0 GoodBond From CBL to GOBO..200 us 1200 100) SCMT-CB -io GR j 0 ;., 10 t` 20 ' 30 ao 50 60 70 ti 90 100 i 120 ' 130- i - 1401 ;. f r .a., UIIIIIIN�I. I III.M VW 'WMOW I Mm cm r $ O --yz t< S z` � " E R � T $ •s — Ri G 7 — iE I � l c � PA F a y s S f� J S � Tye 44 1470 1480 1490 1500 1510 1520 ; 1530 1540 1550 ; 1560 +--- 1570 ; 1580 L90 1600 1610 s • 1620 1630 1640 1660 1670 1680 6NS s > r - y i i ,r: l �i ` s � s rt r ,E t ti i I i— s `r 1` J A r' ' F l ~ 169V 1700 1710 1720 1730 1740 1750 1760 1770 1780 1790 1800 lb20 1830 1850 1850 — 1860 1 187C 1880 , 1900 ;TE ISCMT -cy l f I �f f ar S J 3i s ` ,y ' s — r-- M —'c z „AyMA 1910 •i -� 1920 1930 1990 1950 ; 1960 1 1970 1 1980 1990 ; I 2000 = 2010 ; 2020 2030 204( 2050 2060 2070 ; 20P0 1 St «Z -j - t � . x ' L ~ ~;- L A- - _ g - a3 L030 1 2140 I 2150 I ; 2160 2170 I 2180 2190 2200 2210 ?220 2240 r 2250 2260 - 227n r ; 2280 229n 2300 ^310 2120 2330 , -90 mil -1j," ill r 1 � rrs aurora- - CB c, t t _ J c� y� t r i c s _ r t `s r c — f r r f- it mil -1j," ill z - MXMA ✓ AVMA b Ir — J C s j d _ - 1 j� � L I S i e:, 2570 2580 ; a —c 2590 ' 2600 ENS A`— LCle t TT ;T 2620 R _S MT s 2630 r _ � R ; 2640 1 � _ 2650 sirs '.660 26-(- 2680 I� J i Iy 2690 2700 , 2710 j z72o 2730 , 2740 2750 ' 2770 2780 a —c - ENS A`— t s r _ � 1 � _ sirs c— I� J i Iy 4 ,j. .., ,rtt{r 0 11VVIIII01.111 i11111lHOWSMAN Transit Time for CBL tTTi 0 mV 10; SCMT-CB us CCL Computed Amplitude (CCLC) PSTP-B -19 V 1 Normalized Average MAP Amplitude (AVMA) SCMT-CB 0 mV 100 Normalized Minimum MAP Amplitude (MIMA) SCMT-CB 0 mV 100 Normalized Maximum MAP Amplitude (MXMA) SCMT-CB 0 mV 100 GoodBond From CBL to GOBO.'. TIME -1900 - Time Marked every 60.00 (s) Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image ) Index Scale: 5 in per 100 It Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -201918:54:36 Cement Evaluation Log: Parameters CBL Temperature 244 in ViNro I6UM i MAP Peak Detection TO—Delay and Noise Gate ( SCMT-CB 1153.57 us Arbitrary 'SHT I Surface Hole Temperature Borehole 68 degF Depth Zone Parameters 0 16.08 1 28.1 I MMSA 0.85 depth are 28.1 0 Cement Evaluation Log: Parameters Gain Acquisition System Version Maxwell 2019 9.0.106845.3100 Application Patch I Mhn fines niDr,-Tk,,.o:. onln n n n 1/H O 113184 Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[4]:Up Up 3733.56 ft 4081.74 ft 15 -Oct -2019 15 -Oct -2019 ON -16.02 ft No Evaluation 11:19:45 AM 11:32:40 AM Log All depths are referenced to toolstring zero Company: ConocoPhill ips Alaska, Inc. WelIAD-125A Cement Evaluation Loci7 Loq[41-Up-S 0055 Description: SCMT VDL Image Format: Log (SCMT_VDL_Image) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -2019 18:54:46 TIME -1900 - Time Marked every 60.00 (s) Gamma Ray (GR) PSTP-B 0 gAPI 150 Relative Bearing (RB_SCMT) SCMT-CB -------------------- 0 deg 360 Transit Time for CBL (TT) SCMT-CB CBL Amplitude (CBL) SCMT-CB o -------------10 mv CBL Amplitude (CBL) SCMT-CB 0 mV 100 Good Bond (GOBO) 0 mV 10 Normalized Average MAP —Amplitude (AVMA) SCMT-CB 0 mV 100 Normalized Minimum MAP _ Amplitude (MIMA) SCMT-CB 0 mV 100 i.�r«-.-.;�, Y•. S .� ,1 E '#�����{�� s' ((r ut5�'tii� tr;� ',' It �'s,;i��lfiiirF', s .rl( I�ii��i2�Cxtu�?�� �I S ., 910 3920 3930 3990 3950: 3960 •, .. 3970 � r 398(' 'r i 9000 1, 4010 9036 __ 2i 4040 ' ' XM - j ((:' CtlW5OBSA . I _ T. ;TE' . V_� s t ---� -- 4060 R�_SCMT 4070 4080 V - Gamma Ray (GR) PSTP-B Cable CBL Amplitude (CBL) SCMT-CB Min Amplitude Max d 8 S 8 8 g 8 R g 0 gAPI 150 Tension 0 mV 10 ^ ^ (TENS) Relative Bearing (RB_SCMT) CBL Amplitude (CBL) SCMT-CB VDL VariableDensity (VDL) 2000lbf 0 SCMT-CB CBL Amplitude Mapping Image (0 - SCdIeg "-"-'---` 0 mV 100 200 us 1200 100) SCMT-CB �-'-----" 0 d 360 Good Bond (GOBO) Transit Time for CBL (TT) 0 mV 10 SCMT-CB Normalized Average MAP 200 us 400 Amplitude (AVMA) SCMT-CB O mV 1001 ccl Ch I A II}I I4 RI r 11}P H P PSTP-B -19 V 1 TIME 1900 -Time Marked every 60.00 (s) I I Normalized Minimum MAP _ Amplitude (MIMA) SCMT-CB _ 0 mV 100 Normalized Maximum MAP Amplitude (MXMA) SCMT-CB 0 mV 100 -GoodBond From CBL to GOBO.'- Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image) Index Scale: 5 in per 100 ft Date: 15-Oct-2019 18:54:46 Index Unit: It Index Type: Measured Depth Creation Cement Evaluation Log: Parameters Parameter Description Too[ Value Unit BHT Bottom Hole Temperature Borehole 212 tlegF C63G SCMT CBL3k Peak Detection TO_Delay and Noise Gate SCMT-CB 204.63 us CBLG CBL Gate Width SCMT -CB 40 us CBRA CBL LQC Reference Amplitude in Free Pipe SCMT-CB 93 mV THNO Nominal Casing Thickness-Zoned along logger depths WLSESSION 0.263 in DC MODE Depth Correction Motle DepthCorrection Real-time DFD Drilling Fluid Density Borehole 10 Ibm/gal DFT_CATEGORV Drilling Fluid Type Borehole Oil DTMD Borehole Fluid Slowness Borehole 244 us/k FPD Elevation of Permanent Datum(PDAT) above Mean Sea Level WLSESSION D k GGRD Geothermal Gradient Borehole 1 0.01 degF/ft GOBO_CURR Good Bond in Arbitrary Cement SCMT-CB 2.18 mV GTSE Generalized Temperature Selection, from Measured or Computed Temperature Borehole GTEM LINEST(RT) — MAPG SCMT MAP Peak Detection TO—Delay and Noise Gate SCMT-CB 153.51 us MATT_CURR Maximum Attenuation in Arbitrary Cement SCMT-CB 16.08 dB/k MCI Minimum Cemented Interval for Isolation SCMT-CB t.25 fi MMSA MAP Minimum Sonic Amplitude SCMT-CB 4.91 mV MSA Minimum Sonic Amplitude 8CMT-CB 0.85 mV MSA_CURR ni Minimum Soc Amplitudein ArbrharyCement SCMT-CB 0.85 mV PDAT Permanent Datum WLSESSION MSL RUN_SNUM Run Sequence Number WSDRUN 1 SHT Krone =1w1jMQ= Surface Hole Temperature Borehole 68 tlegF Cement Evaluation Log: Parameters Parameter Description Tool Value Unit CMTM SCMT Operating Mode SCMT-CB Log MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 1800 ftm PCCG PSP Downhole CCL Gain PSTP-B 24—Arm Caliper• • Main Pass • • ■ 12 dB 1-1..............�o.o.., version Maxwell 2019 9.0.106845.3100 Application Patch Wireline_NPD-ThruBit-2019.0_9.0.109638 Wireline_NPD-LEE-2019.0 9.0.111464 Wireline—NPD-WPP-2019.0 9.0.113184 Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data 24 -Arm Log[4]:Up Caliper Log Up 25.90 ft 4080.94 ft 15 -Oct -2019 4:04:07 PM 15 -Oct -2019 6:05:31 PM ON -12.31 ft No All depths are referenced to toolstring zero 'E Company:ConocoPhillips Alaska, Inc. WellAD-125A 24 -Arm Caliper Lo : L 4 :U :S005 Description: PMIT Radii Log Format: Log ( PMIT Radii Log) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -201918:54:50 'PMIT Status (PMIS) PMIT-A 1 - Bit7 - : PMIT Logging speed in accordance with selected resolution ❑ PMIT Logging too fast for selected resolution TIME_1900 - Time Marked every 60.00 (s) Fully -Op ened Fingers Correcti on Flag (FFCO_ FLAG) PMIT-A 0 30 PMIT Status MIT -A Corrected Radii (CRAD) ([1] - [24]) 1 in Internal Radius Minimum Value (IRMN PMIT) PMIT — d o 0 0 o s o s o 0 0 0 o 0 0 0 0 0 0 0 0 o N Cable (TENS) ion 0 Ibf 2000 1.25 n 1.75 Explicit Normalization PMIT -CRAM PMIT-A (in) internal Radius Maximum Value (IRMX_PMIT) PMIT-A CCL Computed Amplitude (CCLC) PSTP-B 1.25 in 1.75 a o Casing/Pipe Nominal Inner Radius (CIRC) PMIT-A 1.25 in 1.75 Explicit Nomlalization PMIT - CRMN PMIT-A ( ) -10 V 1 Gamma Ray (GR) PSTP-B Internal Radius Averaged Value(PMIS)m (IRAV_PMIT) PMIT-A Relative Bearing (RB—PMIT) PMIT-A 0 gAPI 1501.25 n 1.751 0 deg 360 s So I; — i i r-W.L- MQM ROL= z w � a,00 IIFF �-T 7 r.7 .- _ ,,� -, — �a�— l ¢R M) TENS i Cable Tension Internal Radius Minimum Value PMIT Status Corrected Radii (CRAD) ([1] - [24]) d o 0 0 0 0 0 0 0 0 o g (TENS) IRMN_PMIT PMIT-A ( ) (PMIS) o o o 0 0 0 ¢ 0 4 0 ------- - 0 Ibf 2000 PMIT-A in 1.25 in 1.75 1 1 Explicit Normalization CCL internal Radius Maximum Value Computed (IRMX_PMIT) PMIT-A Fully -Op PMIT -CRAM PMIT-A Amplitude Bred (in) (CCLC) 125 In 1.75 Fingers o Co S o o S o 0 0 0 0 PSTP-B Correcti on Flag o 0 0 0. 0 0 0 0 o g Casing/Pipe Nominal Inner -10 V 1 Radius (CIRC) PMIT-A ( FFCC FLAG) Explicit Normalization Gamma Ray 1.25 In 1.75 (GR) PSTP-B PMIT-A 0 30 PMIT - CRMN PMIT-A (in) API 150 Internal Radius Averaged Value Relative Bearing (RB PMIT) PMIT-A (IRAV_PMIT) PMIT-A LTIME' 1.25 in 1.75 0 deg 360 _1900 -Time Marked every 60.00 (s) PMIT Status (PMIS) PMIT-A 1 - Bit7 - : 0 PMIT Logging speed in accordance with selected resolution L] PMIT Logging too fast for selected resolution Description: PMIT Radii Log Format: Log ( PMIT Radii Log) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -201918:54:50 24 -Arm Caliper Log: Parameters Parameter Description Tool Value Unit BAD FINGERS Bad Fingers Ignored for Processing PMIT-A Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok] EXCO Eccentering Correction PMIT-A Disallow FOCO Finger Offset Correction PMIT-A Disallow FWCO Finger Wear Correction PMIT-A Disallow OVCO Ovalization Correction PMIT-A Disallow WLI Logged Interval (for wear correction) PMIT-A p ft 24 -Arm Caliper Log: Parameters Parameter Description Tool Value Unit MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 2181 fuh PCCG PSP Downhole CCL Gain PSTP-B 12dB I 1 - / - • • 7Wjrresloine77 Acquisition System on Maxwell 2019 6845.3100 Application Patch _NPD-ThruBi Wireline _NPD -LEE -2019.0 9.0.111464 Wireline—NPD-WPP-2019.0-9.0.113184 Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data 24 -Arm Caliper Log Log[2]:Up Up 3686.97 ft 4080.45 ft 15 -Oct -2019 3:46:24 PM 15 -Oct -2019 3:59:27 PM ON -13.15 ft No All depths are referenced to toolstring zero 90 Company: ConocoPhillips Alaska, Inc. WellAD-125A 24 -Arm Caliper Lo:Lo 2:U :S005 Description: PMIT Radii Log Format: Log ( PMIT Radii Log) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -201918:56:01 TIME_1900 - Time Marked every 60.00 (s) PMIT Status (PMIS) PMIT-A 1 - Bit7 - 0 PMIT Logging speed in accordance with selected resolution PMIT Logging too fast for selected resolution Internal Radius Minimum Value (IRMN PMIT) PMIT-A Fully -Op ened Fingers Conecti on Flag (FFCO FLAG) PMIT-A 0 30 _ C O N O O O m 0 d o 0 o S o 0 Cable(TENS) ion 0 lot 2000 125 m 1.75 Explicit Normalization PMIT -CRAM PMIT-A (in) Internal Radius Maximum Value IRMX_PMIT PMIT-A ( ) CCL Computed Amplitude (CCLC) PSTP-B 1.25 in 1.75 Q 4 0 0 ^000s00000 0 o Casing/Pipe Nominal Inner Radius (CIRC) PMIT-A 125 in 1.75 Explicit Normalization PMIT - CRMN PMIT-A (in) -10 V 1 PMIT Status PMIS) PMIT-A 1 1 Gamma Ray (GR) PSTP-B Value( Internal Radius Averaged ValuePMIS (IRAV_PMIT) PMIT-A Corrected Radii (GRAD) ([1] - [24]) Relative Bearing (RB—PMIT) PMIT-A 0 gAPI 150 1.25 n 1.75 in 0 deg 360 3 ,00 3850 I - i fti QOO i i RI&kRMIT _ doso — GR I C _ 7I TENS I Cable Tension Internal Radius Minimum Value PMIT Status Corrected Radii (CRAD) ([1] - [241) o e M g g o o (TENS). PMIT-A (PMIS) Q o 0 0 0 0 0 0 0 0 o N - - - - - - 0 Ibf 2000 PMIT-A in 1.25 in 1.75 Explicit Normalization 1 1 CCL Internal Radius Maximum Value Fully -Op Computed (IRMX_PMIT) PMIT-A PMIT -CRAM PMIT-A Amplitude ened (in) (CCLC) 1.25 In 1.75 Fingers y o 0 0 0 0$ o 0 0 0 0 PSTP-B Correcti on Flag Q000Q000000 Casing/Pipe Nominal Inner -10 V 1 Radius (CIRC) PMIT-A (FFCO FLAG) Explicit Normalization Gamma Ray 1.25 In 1.75 (GR) PSTP-B PMIT-A 0 30 1 PMIT - CRMN PMIT-A (in) 0 gAPI 150 Internal Radius Averaged Value Relative Bearing (RB—PMIT) PMIT-A (IRAV—PMIT) PMIT-A 1.25 in 1.75 0 deg 360 PMIT Status (PMIS) PMIT-A 1 - Bit7 - : 0 PMIT Logging speed in accordance with selected resolution PMIT Logging too fast for selected resolution TIME -1900 - Time Marked every 60.00 (s) Description: PMIT Radii Log Format: Log ( PMIT Radii Log) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 15 -Oct -201918:56:01 24 -Arm Caliper Log: Parameters Parameter Description Tool Value Unit BAD_FINGERS Bad Fingers Ignored for Processing PMIT-A [Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok, Ok] EXCO Eccentering correction PMIT-A Disallow FOCO Finger Offset Correction PMIT-A Disallow FWCO Finger Wear Correction PMIT-A Disallow OVCO Ovalization Correction PMIT-A Disallow WLI Logged Interval(forwear correction) PMIT-A -6- ry W-t.,::..� 24 -Arm Caliper Log: Parameters Parameter Description Tool Value Unit MAX -LOG -SPEED Toolstring Maximum Logging Speed WLSESSION 2181 ry/6 PCCG PSP Downhole CCL Gain pSTP-B 12 dB SCMT-CB (Slim Cement Mapping Tool, 1-11/16 OD) Calibration - Run Cement Evaluation Log Primary Equipment Slim Cement Mapping Sonde SCMS-CB 8043 CBL and MAP Amplitude Normalization - Measurements Master (Measured): 05:38:49 29 -Mar -2019 Measurement Nominal Low Limit Actual High Limit CBL 3 ft Temperature/Pressure CompensatedMaster Raw Amplitude (at 0 degree)MAP 1350.0001000000 1241053 1700.000 1 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) 7Un4itPhase Master 1075.000 500.000 1420634 1650000 MAP 2 TemperaturelPressure Compensated Raw Amplitude (at 0 degree)MAP Master 1075.000 500.0001141.902 1650.000 3 TemperaturelPressure Compensated Raw Amplitude (at 0 degree) mMaster 1075.000 500.000 958.558 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) mV Master 1075.000 500.000 954.423 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) mV Master 1075.000 500.000 997.028 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) mV Master 1075.000 500.000 915.676 1650.000 MAP 7 TemperaturelPressure Compensated Raw Amplitude (at 0 degree) mV Master 1075.000 500.000 925.023 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) mV Master 1075.000 500.000 1015.778 1650.000 CBL 3 it Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 7350.000 1000.000 1410.170 1700.000 MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 1056.697 1650.000 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 996.559 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 901.264 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 7017.958 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 1170.775 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 1786.125 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 1484.957 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) mV Master 1075.000 500.000 1141.115 1650.000 CBL 3 ft Temperature/Pressure Compensated Raw Amplitude (at 180 degree) mV Master 1350.000 1000.000 1401.150 1700.000 MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) mV Master 1075.000 500.000 922.542 1650.000 MAP 2 TemperaturelPressure Compensated Raw Amplitude (at 180 degree) mV Master 1075.000 500.000 942.253 1650.000 MAP 3 TemperaturelPressure Compensated Raw Amplitude (a[ 180 degree) mV Master 1075.000 500.000 965.830 1650.000 MAP 4Temperature/Pressure Compensated Raw Amplitude (at 180 degree) rW Master 1075.000 500.000 1184.970 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) mV Master 1075.000 500.000 1463.005 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) mV Master 1075.000 500.000 1336.420 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) mV Master 7075.000 500.000 7003.001 7650.000 MAP 8 TemperaturelPressure Compensated Raw Amplitude (at 180 degree) mV Master 1075.000 500.000 901.122 1650.000 ral 2 mot i 1a6n nnn 1 1nnn nnn I 1snr; SRS nnn not) R--'-- Raw Amplitude (at 270 degree) PBMS RTD Well Thermometer Master Calibration Master (EEPROM): 01:00:00 29Jan-2019 . ___."` -------- ""' ""' 1 I ■ MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) my Master 1075.000 500.000 738.490 1650.000 280.2601 -68.90785 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 949.633 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 749.387 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 679.314 1650.000 Compensated MAP 5 Temperature/Pressure (t270degree) Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 815.016 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 774.294 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 875.271 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) mV Master 1075.000 500.000 886.907 1650.000 CBL and MAP Amplitude Normalization - Coefficients Master (Measured): 05:38:49 29 -Mar -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Normalization Temperature in SFT Tube degF Master 73.00 CBL Correction Factor Master 0.072 MAP i Correction Factor Master 0.116 MAP 2 Correction Factor Master 0,119 MAP 3 Correction Factor Master 0.134 MAP 4 Correction Factor Master 0.125 MAP 5 Correction Factor Master 0.108 MAP 6 Correction Factor Masier 0.114 MAP 7 Correction Factor Master 0 112 MAP 8 Correction Factor Master 0,122 PSTP-B (PSP Telemetry Platform B - Quartz) Calibration - Run Cement Evaluation Log I Primary Equipment: PBMS-B Calibration Parameter : JIG-BKGD I] li•6Ec7 2767 PBMS CQG Master Calibration PBMS RTD Well Thermometer Master Calibration Master (EEPROM): 01:00:00 29Jan-2019 PBMS RTD THERM (Master) RTD Coefficients Fb*'2 Tt"0 Tt''1 Tt"2 Tt"3 Tt"4 Tt"5 Tt*'0 16---L -510.5094 280.2601 -68.90785 11.84148 A.7243377 0 PBMS CQG Master Calibration PBMS Gamma Ray Master Calibration Master (EEPROM): 01:00:00 27 -Mar -2006 PBMS GR MODEL (Mast(T) GR Coefficients Fb*'2 Fb"3 Rt"O Rt**l Rt"0 2000 2010 PBMS CQG Master Calibration Master (EEPROM): 01:00:00 29Jan-2019 PBMS _P_GAUGE_PRES CQG Pressure Model Coefficients (Master) Fb"0 Fb"1 Fb*'2 Fb"3 Fb'*4 Fb"5 PMIT-A (PSP Multifinger Imaging Tool A - 24 fingers - 1 11/16 in.) Calibration - Run 24 -Arm Caliper Log Primary Equipment MITS Inclinometer Inclinometer 766 Multifnger Imaging Tool Sonde A- 24 STD Fingers Fc"1 -1.041184 T238443E-05 -9.863378E-11 -1.907462E-16 4.090542E-20 0 Fc*`2 8.369312E-07 4.464787E-11 8.144614E-16 0 0 0 Fc**3 -1.887044E-12 2.99956E-16 0 0 0 0 Fc**4 0 o 0 0 0 0 Fc"5 0 0 0 0 0 0 PBMS_P_GAUGE _TEMP CQG Temperature Model Coefficients (Master) Fc**0 Fc -1 Fc"2 Fc**3 Fc"4 Fc"5 Fb**0 112.81 -0.0003650262 7.900632E-09 1.590558E-13 -2.119052E-17 7686862E-21 Fb'*Y -0.0060177 1.669224E-08 2.127497E-13 -3.819098E-18 -9.971426E-22 0 Fb"2 3.12486E-08 2.95894E-13 -5.140385E-18 0 0 0 Fb"3 -4.181663E-13 1.245043E-17 0 0 0 0 Fb"4 0 0 0 0 0 0 Fb**5 0 0 0 0 0 0 PSMS_CQGf _FCLK_FREQ CQG Clock Frequency Model Coefficients (Master) (Fb'-Fc')"0 (Fb'-Fc')**1 (Fb'-Fc')*'2 (Fb'-Fc')"3 (Fb'-Fc')'*4 (Fb'-Fc)"5 (Fb'-Fc')"0 31086.64 0.004102663 4.392665E-07 -6.462592E-11 8.999487E-16 -7.690212E-20 PBMS CQG_FCLK TEMP CQG Clock Temperature Model Coefficients (Master) (Fla' -Fc')"0 (Fb'-Fc')"Y (1:b'-Fc')**2 (Fb'-Fc')"3 (Fb'-Fc')"4 (Fb'-Fc')"5 (Fb'-Fc')**0 110.1599 -0.005718552 -2.908009E-08 1.509141E-13 -1.738458E-17 7.869896E-22 PMIT-A (PSP Multifinger Imaging Tool A - 24 fingers - 1 11/16 in.) Calibration - Run 24 -Arm Caliper Log Primary Equipment MITS Inclinometer Inclinometer 766 Multifnger Imaging Tool Sonde A- 24 STD Fingers MITS-A 766 Calibration Parameter : [Master] (Tool Deviation During Inclinometry Calibration) 35 [Before/After] (List of Fingers to be excluded from Eccentralization Correction (in Before Calibration)) (Before Calibration Ring 1 Diameter) 2.000 (Before Calibration Ring 2 Diameter) 2.500 (Before Calibration Ring 3 Diameter) 3.500 (Before Calibration Ring 4 Diameter) 4.500 [Master] Inclino Master Calibration - Inclinometry Accumulations: Tool Vertical. Master (Measured): 13:44:52 29 -May -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Inclinometer INCX Vertical Average Accumulation Master 517.734 m Inclinometer INCX Vertical Max. Deviation Accumulation Master 0.734 m Inclinometer INCY Vertical Average Accumulation Master 514.266 m Inclinometer INCY Vertical Max. Deviation Accumulation Master 0.734 T Inclino Master Calibration - Inclinometry Accumulations: Tool Inclined, Finger 1 at Top. Master Measure(d): 13:44:52 29 -May -2019 Measurement .......�.�. .......ni i Milan i rmrr i r Inclinometer INCXO Degree Average Accumulation _...- --- Master _......_. __.. _.....- - 557.916 a.. ....... Inclinometer INCX 0 Degree Max. Deviation Accumulation Master 0.916 Inclinometer INCY 0 Degree Average Accumulation Master 568.485 m Inclinometer INCY 0 Degree Max. Deviation Accumulation Master 0.515 Inclino Master Calibration - Inclinometry Accumulations: Tool Inclined, Finger 1 Rotated 90 Degrees. Master (Measured): 13:44:52 29 -May -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit Inclinometer INCX 90 Degree Average Accumulation Master 454.099 m Inclinometer INCX90 Degree Max. Deviation Accumulation Master 7099 m Inclinometer INCY 90 Degree Average Accumulation Master 534.085 Inclinometer INCY 90 Degree Max. Deviation Accumulation Master p,g15 m Inclino Master Calibration - Inclinometry Accumulations: Tool Inclined, Finger 1 Rotated 180 Degrees. Master (Measured): 13:44:52 29 -May -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Inclinometer INCX 180 Degree Average Accumulation Master 470754 m Inclinometer INCX 180 Degree Max. Deviation Accumulation[ Master 0.754 m Inclinometer INCY 180 Degree Average Accumulation Master 467.512 m Inclinometer INCY 180 Degree Max. Deviation Accumulation Master 0,512 Inclino Master Calibration - Inclinometry Accumulations: Tool Inclined, Finger 1 Rotated 270 Degrees. Master (Measured): 13:44:52 29 -May -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Inclinometer INCX 270 DegreeMaster Average Accumulation 567.995 Inclinometer INCX 270 Degree Max. Deviation Accumulation Master 1.005 m Inclinometer INCY 270 Degree Average Accumulation Mosier 472.000 m Inclinometer INCY 270 Degree Max. Deviation Accumulation Master 1.000 Inclino Master Calibration - Inclinometry Coefficients Master (Measured): 13:44:52 29 -May -2019 Measurement Unit Phase Nominal Low Limit;Actual High Limit I InclinometerX when Vertical Master 500000 0 734 1000.000Inclinometer Y when Vertical Master 500.000 0 67 1000.000X Sensitivity/ Y Sensitivity Master 1.000 0 0 2.000Inclinometer Deviation Factor Master 300.000 50.000 12 550.000Inclinometer Relative Beadng Offset degMaster 0 -360.000 74 360.000 Fingers Calibration - Fingers Wellsite Calibration - Bad Fingers List Before (Measured): 15:02:27 15 -Oct -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Bad Fingers List Before Fingers Calibration - Fingers Wellsite Calibration - Coefficients Before (Measured): 15:02:27 15-0ct-2019 After (Measured): 184431 15-0ct-2019 Measurement Unit Phase Nominal Low Limit Actual High Limit m Gain -Finger -0 Before After After -Before -- — -- _— -- __ 1.00 0.99 -0.01 _— -- _— m Gain - Finger -1 Before After After -Before -- — — — -- -- 0.99 0.98 -0.01 _— — -- Gain-Finger-2 Before -- __ 0.99 _- Nner After-Before __ -- - _- u-er -0.02 - Gain - Finger - 3 Before After After-Before - -- -- __ - -- 0.99 0.98 -0.01 _- -- -- m Gain - Finger -4 Before After After-Before - -- -- _- - -- 0.99 0.97 -0.02 _- - -- Gain-Finger -5 Before After After-Before - --- -- -- - __ 0.99 1.10 0.11 -- "- m Gain -Finger -6 Before After After-Before - -- -- -- - -- 1.00 0.99 -0.01 -- - m �`•-J Gain - Finger - 7 Before After After-Before - -- -- -- - -- 1.00 0.99 -0.01 -- --- -- Gain-Finger-8 Before After After-Before - -- -- _- - -- 098 0.98 0.00 - -- Gain-Finger -9 Before After After-Before - -- -- _- - - 0,99 0.97 -0.02 - -- -- Gain - Finger - 10 Before After After-Before - -- -- -- - -- 1.00 0.99 -0.01 -- -- - Gain - Finger -11 Before After After-Before - -- -- __ -- -- 0.99 0.99 0.00 _- -- - Gain-Finger-12 Before After After-Before - -- -- - -- -- 098 0.97 -0.01 _- -- - Gain - Finger -13 Defore After After-Before - -- -- - -- -- ().98 0.97 -0.01 _- - -- Gain-Finger -14 Before After After-Before - -- - - -- --" 101 0.99 -0.02 - _- Gain -Finger -15 Before After After-Before - -- -- - -- -- 1.00 0.97 -0.03 --- - Gain-Finger-16 Before After After-Before - -- -- - -- -- 1.00 1.08 0.08 -- - -- m Gain -Finger -17 Before After After-Before -- -- -- - - -- 0.99 1.01 0.02 _- - _- Gain - Finger - 18 Before After After-Before -- -- "-- - -- -- 0,99 0.98 -0.01 _- -- - m m Gain - Finger -19 Before After After-Before -- -- - - -- -- 0.99 1.00 0.01 - -- m Gain-Finger-20 Before After After-Before - -- -- - -- __ 098 0.96 -0.02 -- m Gain-Finger -21 Before After After-Before - -- -- - -- _- 1.00 0.99 -0.01 -- _- W m Gain-Finger-22 Before After After-Before - __ -- - __ -- 1.00 0.99 -0.01 - - _- m Gain-Finger -23 Before After - -- - -- 1.00 0.99 -- -- T After -Before -- _- -0.01 _- Offset -Finger -0 in Before After After -Before -- --- - - -- -- 0.02 0.03 0.01 -- Offset -Finger -1 in Before After After -Before -- - - _- -- - 0.03 0.04 0.01 _- - Offset -Finger -2 in Before After After -Before -- - -- - -- -- 0.02 0.06 0.04 -- - Offset -Finger -3 in Before After After -Before -- - -- -- - -- 0.04 0.05 0.01 -- - - m m Offset -Finger -4 in Before After After -Before -- -- -- -- - _- 0.04 0.08 0.04 -- - Offset -Finger -5 in Before After After -Before -- -- -- -- - -- 0.04 -0.39 -0.43 --- -- -- m Offset-Finger -6 in Before After After -Before - -- -- -- -- -- 0.01 0.05 0.04 - - -- W Offset-Finger-7 in Before After After -Before -- - -- - -- -- 0.02 0.05 0.03 -- - - m Offset -Finger -8 in Before After After-Before -- -- - -- -- -- 0.04 0.05 0.01 -- -- - m Offset -Finger -9 in Before After After -Before -- _- - -- _- - 0.04 0-06 0.02 - _- Offset - Finger - 10 in Before After After -Before -- _- -- -- _._ -- 0.01 0.03 0.02 -- - -- Offset - Finger - 11 in Before After After -Before -- - -- -- _- -- 0.03 0.03 0.00 --- - -- m Offset -Finger -12 in Before After After-Before -- - -- -- - -- 0.04 0.05 0.01 -- -- -- m Offset- Finger -13 in Before After After -Before -- - -- _- - -- 0 04 0.04 0.00 - -- -- m Offset-Finger-14 in Before After After-Before -- -- -- -- - -- 0.00 0.01 0.01 - -- -- Offset- Finger - 15 in Before After After -Before -- - -- -- -- - 0.02 0.02 0.00 ---- _- m Offset -Finger -16 in Before After After -Before - -- -- - -- --- 0.03 -0.10 -0.13 ---- - Offset -Finger -17 in Before After After -Before - -- - -- -- - 0.02 -0.04 -0.06 -- ---- m Offset -Finger -18 in Before After After -Before -- -- - -- -- - 0.04 0.02 -0.02 -- - Offset -Finger -19 in Before After After -Before -- -- - _- - - 0.04 0.00 -0.04 _- _- Offset -Finger -20 in Before - - After --- -- -- -- 0.05 0.05 - - Atter-Betore -- - u.uu Offset -Finger -21 in Before After After-Before -- -- - -- - - 0.02 0.02 0.00 -- -- -- Offset-Finger-22 in Before After After-Before -- -- -- -- -- - 0.02 0.02 0.00 -- -- --- m Offset -Finger -23 in Before After After-Before -- -- - -- 0.02 0.03 - -- Master Finger Calibration - Fingers Master Coefficients Before (Manual Entry): 12:17:2525 -Aug -2019 Measurement Unit Phase Nominal Low Limit Actual High Limit [Master] Sonde Sondex Serial Number Before 766 [Master] RADII Sonde Number Of Fingers Before 24 [Master] Temperature Scale Factor Before 0.010 [Master] Finger Scale Factor Before 0.010 [Master] Master Calibration Units Factor Before 1.000 [Master] Minimum Calibration Diameter in Before 2.000 [Master] Maximum Calibration Diameter in Before 4.500 [Master] Minimum Calibration TCOD Before [Master] Maximum Calibration TCDD Before [Master] Lowest Raw Temperature Reading Noted During Master Calibration Before 495 m Fingers Wellsite Calibration - Coefficients MEAS_TRAD-RING1 (Before) Fingers Wellsite Measured TRAD Ring 1 Unit in Finger 0-7 0.961 0.955 0.959 0.941 0.946 0.945 0.951 0.951 Finger 8-15 0.955 0.965 0.978 0.983 0.992 0.994 1.013 1.010 Finger 16-23 1.007 1.015 0.996 0.991 0.987 0.984 0.978 0.975 MEAS-TRAD-RING1 (After) Fingers Wellsite Measured TRAD Ring 1 Unit in 0-7 0.963 0.965 0.976 0.968 0.970 1.259 0.985 0.988 ['Ingernger nger 8-15 0.996 0.998 7.003 1.003 7.005 1.003 1.007 1.007 16-23 0.997 1.006 0.984 0.977 0.969 0.969 0.967 0.969 MEAS_TRAD-RING1 (Before -After) Fingers Wellsite Measured TRAD Ring 1 Unit in Finger 0-7 0.002 0.010 0.017 0.027 0.024 0.314 0.034 0.037 Finger 8-15 0.041 0.033 0.025 0.020 0.013 0.009 -0.006 -0.003 Finger 16-23 -0.010 -0.009 -0.012-0.014 -0.018 -0.015 -0.011 -0.006 MEAS-TRAD-RING2 (Before) Fingers Wellsite Measured TRAD Ring 2 Unit in Finger 0-7 1.221 1.207 1.203 1.189 1.183 1.180 1.191 1.190 Finger 8-15 1.204 1215 1.227 1.237 1.250 1.262 1.277 1.283 Finger 16-23 1.279 1.298 1.279 1.274 1.262 1.253 1.247 1.233 MEAS_TRAD-RING2 (After) Fingers Wellsite Measured TRAD Ring 2 Unit in Finger 0-7 7.235 1.243 1.229 1.237 1.275 1.504 1.215 1.204 Finger 8-15 1.226 1.227 1.226 1.226 1.220 1.233 1.239 1.249 Finger 16-23 1.239 1.264 1.246 1.246 1.241 1.246 1.252 1.247 MEAS-TRAD-RING2 (Before -After) Fingers Wellsite Measured TRAD Ring 2 Unit in Finger 0-7 0.014 0.036 0.026 0.048 0.032 0.324 0.024 0.014 Finger 8-15 0.022 0.012 -0.001 -0.017 4.030 4.029 -0.038 -0.034 Finger 16-23 -0.040 -0.034 -0.033 -0.028 -0.021 -0.007 0.005 0.014 MEAS_ TRAD_RING3 (Before) Fingers Wellsite Measured TRAD Ring 3 Unit in Finger 0-7 1.730 1.727 1.736 1.778 1.718 1.724 1.731 7.730 Finger 8-15 1.738 1.742 7.744 7.746 1.748 1.754 1.764 1.756 Finger 16-23 1.750 1.760 1.744 1.741 1.738 1.733 1.737 1.733 MEAS_TRAD_RING3 (After) Fingers Wellsite Measured TRAD Ring 3 Unit in Finger 0-7 17371.737 1.746 1.732 1.731 2.008 1.747 1.737 Finger 8-15 1.748 1.749 1.748 1.752 1.753 1.755 1.776 1.756 Finger 16-23 1.729 1.760 1.743 1.741 1.743 1.738 11.743 1.739 MEAS_TRAD_RING3 (Before -After) Fingers Wellsite Measured TRAD Ring 3 Unit in Finger 0-7 0.007 0.010 0.010 0.014 0.013 0.284 0.010 0.007 Finger 8-15 0.010 0.007 0.004 0.006 0.005 0.001 0.012 0.000 Finger 16-23 -0.027 0.000 -0.001 0.000 0.005 0.005 0.006 0.006 MEAS_TRAD_RING4 (Before) Fingers Wellsite Measured TRAD Ring 4 Unit in Finger 0-7 2.203 2.206 2.218 2.221 2.210 2.213 Finger 8-15 2.247 2.255 L2.254 L2.241 2.285 2.276 2.252 2.265 Finger 16-23 2.257 2.277 2.249 2.215 2.213 2.210 MEAS_TRAD_RING4 (After) Fingers Wellsite Measured TRAD Ring 4 Unit in Finger 0-7 2.188 2.209 2.227 2221 2.236 2.369 2.236 2.242 Finger 8-15 2.288 2.302 2.287 2.298 2.323 2.320 2.294 2.314 Finger 16-23 2.162 2.253 2.263 2.223 2.253 2.219 2.211 2.207 MEAS_TRAD_RING4 (Before -After) Fingers Wellsite Measured TRAD Ring 4 Unit in Finger 0-7 -0.015 0.003 0.008 0.013 0.018 0.148 0.026 0.029 Finger 8-15 0.041 0.047 0.043 0.040 0.038 0.044 0.042 0.049 Finger 16-23 -0.095 -0.024 0.009 -0.018 0.004 0.004 -0.002 -0.003 LQC_RADII_RESIDUALS (Before) Fingers Wellsite Calibration Radius Residuals Unit in Finger 0-7 0.006 0.004 0.004 0.0060.004 0.001 0.009 0.009 Finger 8-15 0.006 0.005 0.006 0.003 0.006 0.004 0.015 0.004 Finger 16-23 0.005 0.005 0.005 0.006 0.003 0.005 0.007 0.005 LQC_RADII_RESIDUALS (After) Fingers Wellsite Calibration Radius Residuals Unit in Finger 0-7 0.008 0.002 0.011 0.007 0.008 0.052 0.006 0.010 Finger 8-15 0.006 0.008 0.001 0.001 0.009 0.006 0.016 0.009 Finger 16-23 0.033 0.009 0.005 0.007 0.007 0.003 0.002 0.002 LOC -RADII -RESIDUALS (Before -After) Fingers Wellsite Calibration Radius Residuals Unit in Finger 0-7 0.002 -0.002 0.007 0.001 0.004 0.051 -0.003 0.001 Finger 8-15 0.000 0.003 -0.005 -0.002 0.003 0.002 0.001 0.005 Finger 16-23 0.028 0.004 0.000 0.001 0.004 -0.002-0.005 -0.003 Multi -point Calibration, not corrected for eccentralization BEFORE 0 LQC_RAW_RI NG 1) NG 1 0 LQC_RAW_RING2 (LQC_RAW RING3) LQC_RAW_RI NG4) NG 3 LQC RAW RING4 0.25- (LQC_RAW_RI NG 1) (LQC_RAW RING2) (LQC_RAW RING3) (LQC_RAW_RI NG4) Multi -point 0.10- w 1, 0.0( 0.0� c 0.0, z ry1 0.0( LL • LQC_CORR_RING1 • LQC_CORR_RING2 t LQC_CORR_RING3 0 LQC CORR RING4 on, eccentralizati BEFORE (LQCCORR_RI NG 1) (LQC__CORR_RING2) (LQCCORR RING3) (LQC7_CORR_RING4) 3 G � d U U f U CY J 0.2 MA 0.1 10.1 0.0. _z �1 0.01 91-0.0; U 0 —1 -0.1( -0.1; -0.2( -0.2° nt • LQC_RAW_RING1 • LQC_RAW_RING2 , i • LQC_RAW_RING3 • LQC RAW RING4 Finger ( ft ) AFTER (LQC_RAW_RI NG 1) (LQC_RAW_RI NG2) (LQC_RAW_RI NG3) (LQC_RAW_RI NG4) for 0 5 10 15 20 , i I i i 0 5 10 15 20 ringer ( Ti Multi -point Calibration, eccentralization-corrected AFTER • LQC_CORR_RING1 (LQC_CORR_RING1) RADII _TCOR_RESIDUAL (Before) • LQC_CORR_RING2 (LQC_CORR_RING2) • LQC_CORR_RING3 (LQC_CORR RING3) • LQC_CORR_RING4 (LQC_CORR_RING4) 0.007 0.1 0.067 0.008 0.008 0.009 0.009 0.009 Finger 8-15 0.009 0.08 -0.008 -0.008 7008 -0.008 -0.009 -0.007 0.0 � I 0.009 0.008 0.009 0.007 —0.04- 0.04 0.008 0 0.02 0 z F i 0.00 = a — .�,,. , ry, i -0.02- /0i J -0.04 `d rl -0.0 I -0.0 -0.1 0 5 10 15 20 Finger ( ft) Fingers Master Coefficients RADII _TCOR_RESIDUAL (Before) Fingers Master Calibration Radius Residuals Uni[ in Finger 0-7 0.007 0.007 0.067 0.008 0.008 0.009 0.009 0.009 Finger 8-15 0.009 -0-008 -0.008 -0.008 7008 -0.008 -0.009 -0.007 Finger 16-23 -0.008 0.007 0.009 0.008 0.009 0.007 0009 0.008 Fingers Master Calibration, Maximum Residu< BEFORE 0.15 0.1 la 0.0 J 0 0.0 U) LU of 0.0 ry O -0.0 i 0 (Y -0.01 RADII TCOR RESIDUAL J 2I Primary Equipment: PBMS-13 PBMS-B 2767 Calibration Parameter : JIG-BKGD PBMS RTD Well Thermometer Master Calibration Master (EEPROM): 01:00:0029 -Jan -2019 PBMS RTD THERM RTD Coefficients (Master) TN*It Tf**1 TY*9 TM*Z Tf��4 Tf*+'t i ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ 5 10 15 Finger ( ft ) 20 PSTP-B (PSP Telemetry Platform B - Quartz) Calibration - Run 24 -Arm Caliper Log Primary Equipment: PBMS-13 PBMS-B 2767 Calibration Parameter : JIG-BKGD PBMS RTD Well Thermometer Master Calibration Master (EEPROM): 01:00:0029 -Jan -2019 PBMS RTD THERM RTD Coefficients (Master) TN*It Tf**1 TY*9 TM*Z Tf��4 Tf*+'t Tt"0 -510.5094 280.2601 -68.90785 11.84148 -0 7243377 n ^ v PBMS CQG Master Calibration PBMS Gamma Ray Master Calibration Master (EEPROM): 01:00:00 27 -Mar -2006 PBMS _GR_MODEL (Master) GR Coefficients Fb"2 Fb**3 Rt*`0 Rt"1 Rt"0 7477.789 2000 2010 PBMS CQG Master Calibration Master (EEPROM): 01:00:00 29 -Jan -2019 PBMS_P_GAUGE_PRES COG Pressure Model Coefficients (Master) Fb"0 Fb"1 Fb"2 Fb**3 Fb"4 Fb"5 Fc'*O 7477.789 0.02416301 -2.110041E-07 -7.727152E-11 -1.466805E-15 -3.272912E-20 Fc'*1 -1.041184 -1.238443E-05 -9.863378E-11 -1.907462E-16 4.090542E-20 0 Fc -2 8.369312E-07 4.464787E-11 8.144614E-16 0 p 0 Fc**3 -1.887044E-12 2.99956E-16 0 0 0 p Fc'*4 0 0 0 0 p p Fc"5 10 0 0 0 0 0 PBMS _P_GAUGE-TEMP COG Temperature Model Coefficients (Master) Fc*`0 Fc"1 Fc`*2 Fc**3 Fc"4 Fc**5 Fb"0 112.81 -0.0003650262 7.900632E-09 1.590558E-13 -2.119052E-17-1.686862E-21 Fb"1 -0.0060177 1.669224E-08 2.127497E-13 -3.819098E-18 -9.971426E-22 0 Fb"2 .12486E-08 2.95894E-13 -5.140385E-18 0 p p Fb**3 -0.181663E-13 1.245043E-17 0 p p 0 Fb"4 0 0 0 0 0 0 Fb"5 D D 0 p p 0 PBMS _CQG_FCLK_FREQ COG Clock Frequency Model Coefficients (Master) (Fb'-Fc')"0 (Fb'-Fc')"1 (Fb'-Fc')"2 (Fb'-Fc')**3 (Fb'-Fc' "4 (Fb'-_Fc') (Fb'-Fc')"0 31086.64 D.004102663 4.392665E-07 -6.462592E-11 8.999487E-16 -7.690212E-20 PBMS _ COG _FCLK_TEMP COG Clock Temperature Model Coefficients (Master) (Fb'-Fc')"1 (Fb'-Fc')`*2 (Fb'-Fc')*`3 (Fb'-Fc')"4(Fb'-Fc')*`5 (Fb'-Fc')"0 110.1599 -0.005718552 -2.908009E-06 1.509141E-13 -1.738458E-17 7.869896E-22 PTD dao-olf Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, December 12, 2019 8:34 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1D -125A Pre -Rig CBL Victoria, Yeah. I'll just include it in the 10-404 then to keep it together, which should get dropped off today or tomorrow. Thanks. Dusty Ward Senior Wells Engineer Office: 907.265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, December 12, 2019 8:33 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]KRU 1D -125A Pre -Rig CBL Dusty, Could you drop off a copy to our front desk? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(Dalaska.pov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending if to you, contact Victoria Loepp at (907)793-1247 or Victona.Loeoo@alaskagov From: Ward, Dusty K <Dustv.WardCo)conocophillips com> Sent: Thursday, December 12, 2019 8:12 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: 1D -125A Pre -Rig Progress and clarification Victoria, Do you need the CBL we ran of the cement in the IA to date? Or is the daily log and schematic showing our IA cement depths fine? The log is like 66 pages by itself, and it's for structural support in the subsidence zone. Thanks. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Thursday, December 5, 2019 10:03 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]RE: 1D -125A Pre -Rig Progress and clarification Dusty, Approval is granted to add the 2nd top job in the IA and submit a 10-404 for work completed to date. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(o)a laska.o ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such Information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@oloska.gov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Tuesday, December 3, 2019 5:01 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: 1D -125A Pre -Rig Progress and clarification Victoria, Hope this finds you well. I'm touching base on the original 113-125A approved sundry Pre -rig work (attached). - We're progressing thru the Pre -rig work to set this up for 2020 RWO. o We pumped the IA cement job, but did Not get our top of cement as high as desired in the IA per Pre -rig step 6-7 (TOC looks around 300' instead of within the 70'-200' range we were aiming for). o Remaining scope of the cement procedure includes setting the lower 2-3/8" x 3.5" packer and plug in the new 2-3/8" tubing tail. • After we set that 2-3/8" plug is when you want a 10-404 from my understanding per attached e- mail. - However, we're thinking of doing a 2nd little top -job in the IA to get TOC a little higher across the Subsidence area. Does it consequentially change anything you need from us, if we plan to: o Set the lower packer and 2-3/8" plug AND do a 2nd top mob in the IA? We'd then submit the one 10-404 after Both the above are done to wrap up the pre -rig, but that Won't close out the Sundry. Then we'd submit a second 10-404 post-RWO in 2020 that will close out the actual Sundry. I'm not as familiar with submitting 10-404s on pre -rig work, so wanted to clarify with you that the above path -forward works. I'm in all week if you want to chat too. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 pT0 200 - 04¢ Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, December 5, 2019 10:03 AM To: Ward, Dusty K Subject: RE: 1 D-1 25A Pre -Rig Progress and clarification Follow Up Flag: Follow up Flag Status: Completed Dusty, Approval is granted to add the 2nd top job in the IA and submit a 10-404 for work completed to date, Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeppC@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victma.Loeoo@alasko.aov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Tuesday, December 3, 2019 5:01 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Peirce, John W <John.W.Peirce @conocophillips,com> Subject: 1D -125A Pre -Rig Progress and clarification Victoria, Hope this finds you well. I'm touching base on the original 1D -125A approved sundry Pre -rig work (attached). - We're progressing thru the Pre -rig work to set this up for 2020 RWO. o We pumped the IA cement job, but did Not get our top of cement as high as desired in the IA per Pre -rig step 6-7 (TOC looks around 300' instead of within the 70'-200' range we were aiming for). o Remaining scope of the cement procedure includes setting the lower 2-3/8" x 3.5" packer and plug in the new 2-3/8" tubing tail. • After we set that 2-3/8" plug is when you want a 10-404 from my understanding per attached e- mail. - However, we're thinking of doing a 2nd little top -job in the IA to get TOC a little higher across the Subsidence area. Does it consequentially change anything you need from us, if we plan to: o Set the lower packer and 2-3/8" plug AND do a 2nd top job in the IA? • We'd then submit the one 10-404 after Both the above are done to wrap up the pre -rig, but that Won't close out the Sundry. • Then we'd submit a second 10-404 post-RWO in 2020 that will closeout the actual Sundry. I'm not as familiar with submitting 10-404s on pre -rig work, so wanted to clarify with you that the above path -forward works. I'm in all week if you want to chat too. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 20o044 1473 � = 15 -Nov -19 15NoW8.1WO3 10-125A 50.029-22904.01 SERVICE ORDER DWUJ-00138 FIELD NAME DESCRIPTION I KUPARUK RIVER DELIVERABLE WL DESCRIPTION Caliper, CBL DATA TYPE I FINAL FIELD DATELOGGED Prints 15 -Oct -19 CD's 1 R-34 50-029-22534-00 DWUJ-00142 KUPARUK RIVER WL Caliper FINAL FIELD 20 -Oct -19 1 G-18 :3N 50-103-20142-00 E5C2-00012 KUPARUK RIVER WL LDL FINAL FIELD 29-19 1 N-15 50-029-21592.00 EOSH-00109 KUPARUK RIVER WL LDL FINAL FIELD 30 -Oct -19 1 -09 50-029-21541-00 EOSH•00111 KUPARUK RIVER WL Caliper FINAL FIELD 5 -Nov -19 1 1F-12 50-029-21012-00 DWUJ-00146 KUPARUK RIVER WL PPROF FINAL FIELD 8 -Nov -19 1 1A-01 50-029-20590-00 DWUJ-00147 KUPARUK RIVER WL PPROF FINAL FIELD 9 -Nov -19 1 1H-109 50.029-23595-00 DWUJ-00149 KUPARUK RIVER WL IPROF FINAL FIELD 12 -Nov -19 1 1H-113 50-029.23588-00 E5C2-00013 KUPARUK RIVER WL (PROF FINAL FIELD 13 -Nov -19 1 1 H•117 50-029.23602-00 E5C2-00014 KUPARUK RIVER WL IPROF FINAL FIELD 14 -Nov -19 1 10 A Transmittal Receipt signature confirms that a package (box, (11111qenvelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print IVame Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to chlmberger and CPAI. point. Schlumberger -Private PTD'Joo -b Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Wednesday, October 30, 2019 2:43 PM To: Ward, Dusty K Cc: Rixse, Melvin G (CED); Regg, James B (CED); Schwartz, Guy L (CED) Subject: CPAI: Non -conventional "Rigless" Workover Deployment Option(1 D -125A 200-044) Dusty, In order to review this "rigless" completion operation as an option CPAI has in its "toolbox", we need some additional information as outlined below. Please refer to regulations: 20 AAC 25.285 and 20 AAC 25.286. This information is in addition to the information previously provided. Additional information may be requested. Listed below is information that is needed related to Crane and Operator Requirements: 1. Crane operator must be a certified crane operator 2. Crane operators must be trained on well work including how BOPE equipment works and well conditions 3. All work must meet OSHA requirements and Crane certifications, 4. Proof of certification of the crane and load ratings information. 5. Well Control certification for the crew as conventional BOPS will be used. Schematic of the rig and equipment layout including a schematic of the BOPE, choke and kill lines, choke skid and tanks.(Rig floor/wind wall?) Full HAZOP type review of the operation must be completed and reviewed with the AOGCC. Source of personnel including company man and rig crew and responsibilities must be outlined. Particularly interested in the equipment and specs used by roustabouts. Gas monitoring including methane and H2S monitors. CPAI would like to have this operation in their "toolbox" for use on similar wells. Please outline the typical candidate CPAI would like to apply this "rigless" operation to and the number of candidates estimated. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepproialaska.00v CONFIDENTIAUTY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victono.! oelD C@g aska.00v WELL LOG TRANSMITTAL #905966242 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 1D -125A Run Date: 9/14/2019 20 00 44 3 136 5 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D -125A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22904-01 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D -125A Permit to Drill Number: 200-044 Sundry Number: 319-449 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov The AOGCC DENIES the enclosed application for sundry approval relating to the above - referenced well. The reason for this Denial is the AOGCC requires additional review of this unconventional rigless workover technique prior to approval. A sundry for a conventional workover on this well has been previously approved. Sundry Number 319-293. This Denial is without prejudice to your right to resubmit an application in the future if you are able to provide the necessary supporting information. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless reconsideration has been requested. Sincerely, JerePhicc Chair, Commissioner DATED this 11 day of October, 2019. 3BDMS f'AJ OCT 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 U11 C T Ar,,.7 A k >� Vim,. 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Simulate ❑ Pull Tubing D Change Approved,Frogmm❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Rigless w/o M 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service I] , 200-0444 , 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-22904-01-00 r 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ElNo M .KRLI ID -125A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 Kuparuk River Field /1,11i Oil Pool 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP i) Plugs (MD): Junk (MD): 5,639' 4,051' 4580 3083 i' Jun -12 NONE Casing Length Size MD D Burst Collapse Conductor 74' 16" 121' .'121' Production 4,689' 51/2 4,730' / 3,211' Liner 1,106' 31/2 5,6364,,,_4,049' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5096-5410 3552-3841 � 3.500" L-80 4,529' Packers and SSSV Type: and SSSV MD (ft) and TVD (ft): PACKER - BAKER SABL-3 LINER PACKER D and 3039 TVD KIA SSSV -NONE 12. Attachments: Proposal Summary Wellbore s 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E]Stratigraphic ❑ Development ❑ Service O 14, Estimated Date for 10/25/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ U WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the ocedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Dusty Ward Contact Name: Authorized Title: Wells Engineer Contact Email: Dusty.Ward@cop.com `�/Syr. / Authorized Signature: ' �OI Contact Phone: (907) 265-6531 Y i(iLLp'\. Date: U p.� COMMISSION USE ONLY ConditionZn Commis n so that a representative may witness Sundry Number Plug IntegOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IBDMS � PST 1 5 7019 Post Initia? Yes ❑ No ❑ Spacing EYes ❑No Subsequent Form RequiredAPPROVED BYApprovetl\ �I COMMISSIONER THE COMMISSION Date: %ptvlrio/ V771— T-):',, TL (> yt/0//o//� O'RLGINAL Submit Formand Form 10-403 Revise 017A proved application is valid for 12 months from the date of approval. Attachments in Duplicate _F 't R fn /2 /rn ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 1 Oct., 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West SAK Injector 1D -125A (PTD# 200-044). Well 1D-125 was drilled and completed in August 1998 by Parker 245 as a West SAK water injector. The well was worked over in 2000 and sidetracked by Nordic 3 to become 1D -125A and remain a West Sak injector. In later 2017 the well was reported for suspected IA behavior a leak was found at 726' RKB. The well was patched and put on subsidence watch list. An additional leak occurred in 2018 and was attempted to patch, but unsuccessful ultimately. Heavy internal corrosion of the tubing was also note. The well became a workover candidate to re-establish injection and mitigate subsidence in this single casing 5.5" injector. The hybrid subsidence workover repair of the 3.5" tubing with holes, has so far involve proactively attempting to pump the IA full of cement, except for the top —100' documented in a previous sundry approval (319-293). The new plan is to punch the 3.5" tubing at —60' and install 2-3/8" flush joint injection tubing inside the old 3.5" injection string via a crane and coil unit. This method allows: 1) running a 2-3/8" completion string inside the 3.5" tubing and 2) creating a new monitorable annulus (composite of the old 3.5" tubing and 5.5" casing) for the 2-3/8" injection tubing. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells ID -125A RWO Procedure West yak Injector P&R Tubing PTD #200-044 Pre -Rig Work 1. CMIT-TxIA to 2500 psig to confirm casing integrity and primary downhole barrier. Rig Work MIRU 1. MIRU Coil Unit and Crane on ID -125A. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30 -minute NFT. Verify well is dead. 3. Test BOPE to 250/2,500 psi. NU BOPE. Install in 2-3/8" flush tubulars and top packer 4. RIH with coil to 2-3/8" x 3.5" packer and swap well over to diesel. Perform 30 minute NFT. POOH. 5. MU 2-3/8" flush joint completion with snap latch, 2-3/8" flush joint tubing, and 2-3/8" PBR. 6. RIH final—40-80' with tubulars on Coil. Just before snap latch gets near bottom, get PUW and SOW. 7. Then, snap in latch. PU slightly to confirm latch is set. Pump off of PBR. POOH. 8. RIH with upper packer and seals. Sting into PBR. Set and release from upper packer. 9. Pressure test 2-3/8" tubing to 1500 psi for 10 minutes. 10. Pressure test new inner annulus (primarily between 2-3/8" and cemented in place 3-1/2" tubing, but also the tubing and annulus section that tapers out to 3.5" x 5.5" section in the last 70-90' below surface) to 1800 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests. 12. NO ROPE. 13. RDMO equipment. Page 1 of 1 KUP INJ WELLNAME 1D -125A WELLBORE 1D -125A LzinoCOifl1111�i5 Max Angle B MD TD Flea Name wellbore APvuWI weahom sums Iicl Yl A8S'KB.IIC. WEST SAK 5 0028229 04 01 INJ 64.90 Mo 1ryKe) pet BLm INKS) 2,96]38 5,638,0 SSSV'NONE H2S Ippm1 Dah JHNNWOn End Dale [WO'. 4/11,@OW KB6MIn1 Rlp Rekaze Dah 4250 BJIVI998 10.1i5q, e/£J]p1999: 2qMI Last Tag Vee"I"hemah(sow, 1-hanion DepenlkKB Entl Oale Lad T, SCM ",. 30 BI19Y1019 t WeIIW,e La51 Metl By M9ortbi H.NDEN; za.+ Last Rev Reason I Ena DBp, Rsv RBasOHPertmaie T.Rp, - 911412019 1 wellbore L.se Moa By 1 bworthi Casing Strings .INDUCTORlmn CONDUCTOR DD OnI 16 lB lml 15.06 rup (mcel semBpm 47.5 121.0 IHKBI sen Depen lrw)1_ 121.0 Wvl:n(I 62.58 GCBO Tp TM1reea 8-40 WELDED CoN, Des."S PROM ICTION-Past Sidetpeck OD6n1 5.54 loin) 495 Te Wa) Se+Oegn 41.1 4,730.0 -M QlKe) SBL Depen (Npl (... 3,2110 VM,eh B.. 15.50 Grate iop Thrcatl L -8D BTCM _ TIIBINtl FVNCX', 1140i CazYgoea[...1.. WINDOWA uB On 512 ID(inl 4.00 Top KM 4,6920 4,702.0 Pon IHKBI sM Bepm RVOT( S1Dep WHlan O_. Grave Top ihrca4 CONDUCTOR. 47.5-+310 TUBING LFAK', R6.0 Cazin9 Cee[ripHon LINER OO ORD 312 ID lint 2.99 Tap1aKB1 SM 4,5291 5.636.5 Gen. (WSJ) Se[BepM jN01 (.. 4,049.0 L"NLen B... 9.30 Glatle Tap Th,eaf 480 IBT-MOD Liner Details Top lkKBl Top ITVB1IryNB1 Topind p) Item Oes eom ommaun (m) 4,529 ] 3,1138.9 3396 PACKER BAKER'8ABL3 LINER TOP PACKER 2.780 Tubing Strings G1s uPT:4,4Hpa Tueina D... Do smhe Maa..ID DID TopeRRN se+Bepm lk... Set RpIM1 (NBI IR. NY ON1a GrHe Top. ,2[Ibn TUBING 31.2 299 28.1 L12S7 3,038.9 9.30 LA0 EUE8NM00 Completion Details BRPLE;4.uaa TUP me) Top IHKBI MKR) TopI-I(-) Item Des Co. 28.1 28.1 0.00 HANGER VETCO IDBING tWNGEk Nominal IDInp 3.500 4,459.6 2,9811 35.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2612 4,504A3,0179 BATS LOCATOR BAKER LOCATOR 1 2.937 4,505.8 3,019-0 34.12 PER BAKER AD SPECIAL CLEARANCE PBR WIO SEALS 2.985 T.BING PUNCH) 4501.0 45294 3,038.7 33.46 SEAL ABBY MODEL KBM-22'ANCHOR SFALASSEMBLY 2.985 Ober In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) m CATOR:4,W4.4 P9R:45[fi.B TOP(-) "Ind Top DIKB) MRB) C) Dee Co. 110.0 110.0 0.01 TUBING PUNCH Perforated Tubleg It 5' X 2"4 SPF CIR CHG. O Run Da@ ID(in) deg phase 9/142019 2.992 SEgLA65Y4,SIDA ', 726.0 724.6 9.17 TUBING LEAK TUBING LEAK CONFIRMED By EL -LDL 111251201] 0.000 4,501.0 3,01S.1 34.25 TUBING PUNCH PD6OCNeel Teem, wi EL 1.56"N9 punCM1 .9/412019 2.992 4,560.0 3,064.3 32 fit CIBP 3. 5"D&10 WTFO CIBP, CAL1' 9/4/2019 1 0.000 CIBP', 4GRip PATCH X SURFACE CSG PATCH tlown 3'11"from starter---- 5/2512009 Perforations $ Slots vnNDap -DUCT NPR( Gees TbN-0oM eadmck', n.f<.7ao.o MKIDTaOBS) San (1vD pens Top.Uan. Bim11" IHKBI IHKBI Llnketlbne an0 IsnDW 0l Type 5,O9fi.D 5,1300 3,552.3 3,583.8 930/2000 4.0 (PERF 180 DEG PH, 2S'HC DP 5,160.0 5,194.0 3,6115 3,5429 all DRUGS 4.0 PERE 480 DEG PH, 25"HC DP 5,210.0 5,234.0 3651.6 3,679.7 M 5/302000 4.0 IPERF 180 DEG PH, 2.9 HO DP 5,2520 5,2600 3,696.2 3,7036 A31 51302000 CO (PERF 1800EG PH, 2.5"HC DP (PERF; 5,[a5,O5,130.0- 5,270.0 5,288.0 3,712.7 3,729.3 93012000 4.0 IPERF 180 DEG PH, 25" HC OP 5,298.0 5,304.0 37384 3,743.9 U. 51302000 4.0 IPERF 180 DEG PH.. 2.5" HC DP (PERF, S,ISDM.194.0� 5,3240 5,338.0 3,762.2 3.775.1 WS A2, 5/30/2000 4.0 (PERE 180 DEG PH, 25" HE DP 5,3500 3365.0 3786.1 3,199.8 WS R, SI3N2000 4.0 (PERF 1800EG PH.2SHC DP (PERF, 5,310 Dfi,2Na� 5,375.0 5,384.0 3,809.0 781,2 INS `42. 9292000 4.0 WERE 180 DEG PH,25"HC OP IPER1.. srs, .Da.ttgD- 5,396.0 5,410.0 3.62823841.1 WSAZ. 5/2912000 4.D (PERF 180 DEG PH, ZS"HC DP IPERR%, C4.2ee.V- Notes: General & Safety End case a nmBtmn 4/12000 NOTE MONOBORE INIECTOR IPENHs.a.x4.o- 112009 NOTE 1U125 SIDETRACKED 9242008 NOTE VIEW SCHEMA TIO W/Alaska ScMRONic90 IPERF', 5,3Ma5,338.0- PERFS,wa.O ries. IRERP.OpSA6.3e4e- (PERF, Sax M.41oo-T LINER; 4.ER.7S.WGS 1D -125A Proposed RWO Completion Adapter Tubing Spool 62.5# H-40 e@115'RKB 3.5" Tubing Punched @ 80'-90' RKB to allow old tubing to communicate with IA for monitoring. 5.5" 15.5# L-80 shoe __..J@ 4730' RKB 3.5" Liner @ 4529' RKB to 5636.5' RKB IIA Valve I IOA Valve I Tubing Top Packer w/ 60-80' RKB HYD 511. PBR at top: for seals from Upper assembly. IA Tubing COMPLETION 3-1/2" 9.3# L-80 EUE 8rd 3-1/2" Camco gas lift mandrels DS Landing Nipple (2.812" ID) Baker 3-1/2" SABL-3 Liner Top Packer x W RKB (2.78" ID) 3-1/2" 9.3# L-80 EUE 8rd FLUSH JOINT TUBING COMPLETION 2-3/8" z 3-1/2" Packers and tubing to 30' RKB 2-3/8", 4.6# L-80 HYD 511. (1995".ID; 1.901" drift). (62,000 lbs joint Tensile Yield Strength) (-4500' of pipe = -21,000 Has total dry weight) JK -Latch to tubing Baker PBR: 1.75" ID WFT WidePack: 1.81" ID. Top @ 4554' RKB 1.71" R Nipple PTD 206 - 0 4+ Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Tuesday, September 17, 2019 4:04 PM To: Loepp, Victoria T (CED) Subject: 1D -125A Attachments: 1D -125A APPROVED 10-403 Pull Tubing, Repair Well WO Sundry Application.pdf,, 1D -125A Cemented IA SchemelbRevl.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Hope this finds you well. Per our discussion today, for approved 1D -125A RWO, we'll: - Complete the IA Cement job and - Placement of the lower 2-3/8" x 3.5" packer w/ plug in nipple under the current approved Sundry. We'll then plan to Close that Sundry out with a 10-404. I will make a new 10-403 Sundry for the "Rigless" 2*3/8" flush joint tubing conveyance option we discussed today, and submit that for your review/approval. Sound good? Thanks for your time. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 Adapter Packotis 1D -125A Proposed RWO Completion Tree Tubing COMPLETION 3-1/2" 9.3# L-80 EUE 8rd 3-1/2" Carrico gas lift mandrels DS Landing Nipple (2.812" ID) Baker 3-1/2" SABL-3 Liner Top Packer xxxx' RKB (2.78" ID) 3-1/2" 9.3# L-80 EUE 8rd FLUSH JOINT TUBING COMPLETION 2-3/8" x 3-12" Packers and tubing to 30' RKB 2-3/8",4.6# L-80 HYD 511. (1.995" ID; 1.901 " drift). (62,000 lbs joint Tensile Yield Strength) (-4500' of pipe = -21,000 lbs total dry weight) K -Latch to tubing Baker PBR: 1.75" ID WFT WidePack: 1.81" ID. Top @ 4554' RKB Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Monday, September 16, 2019 7:51 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Re: 1D -125A Workover "Rigless" Option Review Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks. Let's plan for 2pm tomorrow then. Have a good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, September 13, 2019 7:42 PM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]Re: 113-125A Workover "Rigless" Option Review Tuesday at 10 AM or 2 PM would work Sent from my iPhone On Sep 13, 2019, at 3:36 PM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote Victoria, I hope this finds you well. Would there a be a good time this next Monday to Wednesday to come by and discuss a "Rigless" workover deployment option we've been discussing here for the currently approved Rig Workover on 1D -125A? - I attached the original sundry and original proposed schematic. The "Rigless" completion idea would install the "1D -125A ... Rev1" completion instead; which allows ALL the inner string components to be completed Thru Tubing. Similar to a long, jointed patch. - We'd plan to use a Coil unit to convey the Flush Joint 2-3/8" the last little bit. - Primary Barriers would be: Tested casing/cement, and a packer/Plug in the tubing tail as shown in Purple on the Schematic. - Secondary Barriers would be: Packoffs and Coil BOPS. I'm free all afternoon Monday, and the morning and afternoon on Tuesday. Please let me know when works for you and I'll swing by. Let me know if you have any questions off the bat I should make sure I come ready to answer also. Thanks! Have a good weekend. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 <1D -125A Cemented IA SchemelbRevl.pdf> <1D -125A Proposed Schematic.pdf> <1D -125A APPROVED 10-403 Pull Tubing, Repair Well WO Sundry Application.pdf> `'Je Victoria T (CED) From: P7n a0o Sent: Peirce, John W <John.W.peirce Sub, Tuesday, qugust 6, 2p19 �o Conoco lect. Loepp, Victoria T 9.03 AM Phillips.com> RE: [EXTERN (CED) w V Job/Postpone RWO to RU D pri A(PTD 200-044, Sundry 319-203) Chan 125 Follo p Flag. g 2020 Change: Pre -Rig Cement Flag Status: Follow up Flagged Got it. Thanks. 1 will add it to my personal Sundry Tracker John as a 10-404 'To Do, item. From: Loepp Victoria T Sent: Tuesday, August (CED) <Victoria.loe To: Ward, Dust gust 6, 2019 7;44 qM PP@alaska.gov> 20 p [ XTE y K )KRLi 1p ard�a conocophillips-com> Subject: E RNAL y �25q(pTD 2t)p_044, Sundry 319-203) Change; Pre -Rig Cement Job P Dusty, / osteone RWO to Spring Approval is granted to proceed with the spring, please submit a 10-404 for the pre rig Cement cement lob as outlined below and Thanx, Procedure when Com to postpone the RWp Victoria Pleted. until Victoria Loepp Senior Petroleum Engineer State OfgJas ka Oi3 7th Ave Onservation Commission Anchorage AI< ggg01 Work (907)793-12 Victoria.47 Loe '�alaska. ov CONF/ commDENTjAAO N07ICE: This e-mail information. The GCC)' State of message, includin reci unauthoriz glaska and is for the sole anyoftthchm s, contains pient of this e- ed review ent You, cont mail, pleased use or disclosure 5eins int m mo act V' e, e if, e Louc e intended pient or n from glaska Oil etl ictoria Lo without hint nde Loepp at (9071793 1247 first saving or fon ormation maY violate (state may contain confidentia aad as conservation or victoriq. g it and or federal/or Privileged alaskq, ov o that the AOGCC is w. If you are an unintended aware of the mistake in endedlending it }o Frorn: Ward, Dusty K <D Sent: Tuesday, August �sty. W-onoco To: Loepp, Victoria Tst 6, 2019 7:34 qM hilli s.cotn> iubject: RE; (CED) 'Victoria Joe (EXTERNgL]KRU ID -125"U P alaska. ov> 'ictoria, (TD 200-044 Sundry 319-203 cod questions. )Pre -Rig Cementjob/RWO We laid the rig down due to budget is why we aren't performing now. Current plan for next RWO program is start of ^'April-ish 2020 when we have a Rig back; this one would be one of the early ones most likely because it's on the CPF1 side of the field. o There's a small chance we get a rigor could squeeze this workover in on a drilling rig if there's a small gap late this year (once year-end budget is clearer and we see how Q3 goes), but I'd give that a low probability. The goal of still doing the cement job is to: - Test our new approach to slow down subsidence and get this well ready for whenever we can/have budget to perform workover. Thanks. Please holler if you have anymore questions. Appreciate you getting back to me. Good day! Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loeppPalaska eov> Sent: Tuesday, August 6, 2019 7:26 AM To: Ward, Dusty K <Dusty.Ward(@conocophillips com> Subject: [EXTERNAL]KRU 1D-125A(PTD 200-044, Sundry 319-203) Pre -Rig Cement Job/RWO Dusty, Why isn't the workover being completed now as planned? What is the approximate timing of the workover? Tha nx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoePI)Aalaska aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending if to you, contact Victoria Loepp at (907(793-1247 or Victoria.Loepip@aioska.gov From: Ward, Dusty K <> Sent: Monday, August 5, 2019 8:52 AM To: Loepp, Victoria T (CED) <victoria.loeppiiaalaska eov> Subject: FW: 113-125A Pre -Rig Cement Job Victoria, I was just confirming that you saw this? Thanks! Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Ward, Dusty K Sent: Tuesday, July 23, 2019 7:22 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Cc: Peirce, John W <John.W.Pei rce@conocophillips.com> Subject: 1D -125A Pre -Rig Cement Job Victoria, Hope this finds you well. For the approved 1D -125A sundry attached, we're planning to do the Pre -Rig Cement job called out in the summary, but may not be doing the workover until next spring. So we plan to - NOT cut the tubing a this time, but rather do some tubing punches that will occur in the cement job around "'100' RKB. - Put a Shear Off Sub for our isolation in the bottom of the new 2-3/8" completion instead of the plug shown in the schematic. Doing the cement job now along with the drifts required to perform the cement job, should still test our theory of the cement to "freeze" subsidence AS well as give us information that our new technique of 2-3/8" should be able to drift to TD, so that we can carry out a workover operation at a later date. Please let me know if you have any concerns with this plan. Thanks! Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 LOQ Victoria 7 (QED) PTO From: Sent: Loepp, Victoria T To: Tuesday, (CED) Sub' Y August 6, 2019 7:44 AM sect: Ward, Dusty K KRU to Spring 20 200-044, Sundry 319.203) Change: Pre -Rig Cement Job/Postpone Dusty, Approval is granted to proceed with the Pre -rig spring. Please submit a 10-404 for the cement procedure when completed. cementjob as outlined below and to postpone the RWp until Thank, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska oil & Gas Conservation COMM. 333 W. 7th Ave ssion Anchorage, AK 99501 Work: (907)793-1247 Victor��alaskagov CONFIDENTIAIpy NOTICE. t e-mail Commission (gOGCC), StatB message, including in formation The unauthorized `f Alaska and is for the e any attachments, recipient of this eview, e sole use of th contains information from th e-mail, please tl use or disclosure e intended recipients . e Alaska You, contact Vici delete it, without first Saving of such information (1 It m°Y contain c Oil and Gas Con 0110 Loepp of 907 9 or fo may violate state onfitlential and servation ( 1793-1247 or Vic Savi g ( n"ardrng it' and• s° that the AO federal law. If and/orged C�alaska. ov OGCC is aware you are an unintended are of the mistake in sending it to From: Ward, DustyK<Dusty.Ward@conocophillips,com> Sent: Tuesday, August 6, 2018 7:34 AM To: Loepp, Victoria T (CED) <Victoria.loepp@alaskagov> . Subject: RE: [EXTERNAL]KRU 1D-125A(PTD 200-044', Sundry 319.203) Pre -Rig Cement lob Victoria, Good /R WO questions. We laid the rig down due to budget is why we aren't Current plan for next RWp program is start of �q Of the early ones Performing now. ° There's s small likely eeca se it's on the pnl Ish 2020 when we have a Rig back; this one would be one gap late this year (once get a rig or could squeeze this workover Probability. Year-end budget is clearer and w see how In °n a drillin rig if The goal of still doing the cement job is to: Q3goes) oes , g g there's a small - Test our new approach to slow down subsidence and g )but I'd give that a low perform workover. get this well ready for whenever we can/have budget to Thanks. Please holler if you have anymore questions. Good day e AppreciatYou getting back to me. 1 Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Tuesday, August 6, 2019 7:26 AM To: Ward, Dusty K <Dustv.Ward@conocophillips.com> Subject: [EXTERNAL)KRU ID-125A(PTD 200-044, Sundry 319-203) Pre -Rig Cement Job/RWO Dusty, Why isn't the workover being completed now as planned? What is the approximate timing of the workover? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeopoa las ka. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska aov From: Ward, Dusty K <Dustv.Ward@conocophillips.com> Sent: Monday, August 5, 2019 8:52 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Subject: FW: 1D -125A Pre -Rig Cement Job Victoria, I was just confirming that you saw this? Thanks! Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Ward, Dusty K Sent: Tuesday, July 23, 2019 7:22 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Cc: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: 1D -125A Pre -Rig Cement Job Victoria, Hope this finds you well. For the approved 113-125A sundry attached, we're planning to do the Pre -Rig Cement job called out in the summary, but may not be doing the workover until next spring. So we plan to - NOT cut the tubing a this time, but rather do some tubing punches that will occur in the cement job around —100' RKB. - Put a Shear Off Sub for our isolation in the bottom of the new 2-3/8" completion instead of the plug shown in the schematic. Doing the cement job now along with the drifts required to perform the cement job, should still test our theory of the cement to "freeze" subsidence AS well as give us information that our new technique of 2-3/8" should be able to drift to TD, so that we can carry out a workover operation at a later date. Please let me know if you have any concerns with this plan. Thanks! Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D -125A Permit to Drill Number: 200-044 Sundry Number: 319-293 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v✓v✓w. a ogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .f7/� Daniel T. Seamount, Jr. Commissioner DATED this Z d y of June, 2019. RBDMS�-O' JUN 1 11019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN 12 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well X Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing O Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: Workover [21 . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service E] . 200-044 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22904-01-00 ` 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 10-125A ' Will planned perforations require a spacing exception? Yes ❑ No [a 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 51639' ' 4'05'4580 3083 1805psi V/4555 none Casing Length Size MD TVD Buret Collapse Conductor 74' 16" 121' 121' Production 4,689' 512 4,730' 3,211' Liner 1,106' 31/2 5,636' 4,049' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5096.5410 35523841 3.500" L-80 4,529' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER SABL3 Liner Packer 4530 MD and 3039 TVD SSSV -NONE NIA 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G] Exploratory ❑ Stratigraphic ❑ Development ❑ Service I] 14. Estimated Date for 7/16/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ O WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Dusty Ward Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Dusty.Ward@cop.com Contact Phone: (907) 265-6531 Authorized Signature: ��jy ' I— Date: I p,�I 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ ^� /✓, •/'71y Plug Integrity ❑ BOP Test CJ Mechanical Integrity Test Location Clearance ❑ Other: ,rS QP frSf- 110 Z 5o 0 1;, S r5 tr o ZD r5r$ fjhr7✓/cL/gyp r�✓l..,z/ft50 r MVI" 2 1 Post Initial Injection MIT Req'd? Yes uv No ❑/ JUN .G 1 219 Spacing Exception Required? Yes ❑ No M/ Subsequent Form Required: APPROVED BY Approved by:4illii COMMISSIONER THE COMMISSION Date: (o / VTL 6/z o// 9 (01�10/,q ORIGINAL Submit Form and Form 10403 aevt d4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 10 June, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West SAK Injector ID -125A (PTD# 200-044). Well ID -125 was drilled and completed in August 1998 by Parker 245 as a West SAK water injector. The well was worked over in 2000 and sidetracked by Nordic 3 to become ID -125A and remain a West Sak injector. In later 2017 the well was reported for suspected IA behavior a leak was found at 726' RKB. The well was patched and put on subsidence watch list. An additional leak occurred in 2018 and was attempted to patch, but unsuccessful ultimately. Heavy internal corrosion of the tubing was also note. The well became a rig workover (RWO) candidate to re- establish injection and mitigate subsidence in this single casing 5.5" injector. The hybrid subsidence RWO repair of the 3.5" tubing with holes, would involve proactively pumping the IA full of cement, except for the top —100'. This then allows the 3.5" tubing to be cut at —60', and a tapered 3.5" x 2-3/8" injection tubing string ran inside the old 3.5" injection string. This method allows 1) putting cement in the subsided zone to mitigate further subsidence while 2) running a 2-3/8" completion string inside the 3.5" tubing and 3) creating a new monitorable annulus (composite of the old 3.5" tubing and 5.5" casing) for the 2-3/8" injection tubing. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells ID -125A RWO Procedure West Sak Injector P&R Tubing PTD #200-044 Remalnine Pre -Ria Work 1. Pull isolation plugs and get new SBHP. 2. Set lower Composite Plug for Cement job. Punch tubing at -4501' RKB. 3. CMIT-TxIA to 2500 psig. 4. Perform T -POT and T-PPPOT. 5. Get full bore circulation rate for cement job. 6. RU coil. RIH with cement retainer to -4981' RKB. Set retainer. Establish circulation rates. Pump cement job to fill 3.5" x 5.5" annulus from punched holes to -100' RKB. Pull out of hole, circulating our extra cement in tubing. RD coil. 7. CBL and confirm cement TOC is between `70-200' RKB. Check Cement integrity in subsidence zone. 8. RU coil and mill up all cement and composite plugs. RD coil. 9. Set lower 2-3/8" x 3.5" WidePak Packer in 3.5" liner at -4550' RKB. Bullhead Brine or fluid into well to swap it over for RWO. Then set plug in new 2-3/8" tubing tail to trap brine in tubing. 10. Cut 3.5" tubing above TOC at -70' RKB. 11. Set BPV and prepare for rig within 48 hours of rig arrival. Ria Work MIRU 1. MIRU Nabors 7ES on 1D -125A. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30 -minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set and/or confirm BPV as barrier if needed, ND Tree, NU BOPE and testto 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. S. Pull 3-1/2" tubing down to cut (-70' RKB). Install in 2-3/8" flush x 3-1/2" Tubing 6. MU 2-3/8" flush joint completion with snap latch, expansion joints, 2-3/8" flush joint tubing, 2-3/8" x 3-1/2" crossover, and 3.5" hanger. 7. RIH. Just before snap latch gets near bottom, circulate well over to Corrosion Inhibited fluid and Diesel Freeze protect in new 2-3/8" x 3.5" monitorable annulus and new 2-3/8" tubing. 8. Then, snap in latch. Space out using expansion joints. Land 3.5" hanger. 9. Pressure test 2-3/8" tubing to 3500 psi for 5 minutes. 10. Pressure test new inner annulus (primarily between 2-3/8" and cemented in place 3-1/2" tubing, but also the tubing and annulus section that tapers out to 3.5" x 5.5" section in the last 50-60' below surface) to 3000 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests. 12. Install Plug in tubing hanger. 13. ND BO PE. NU tree. Test Tree. 14. RDMO. Page 1 of 1 A- _,, KUP INJ WELLNAME 1DA25A WELLBORE 1D -125A C�a�a�^_^� onoco�Illlps Aiasica,lm all AtWbutes Max Angle B MD TD Field weIIMreAPIIM wenWresxus MDInKa) Act .1.IN(B) VVIESTSAK 500292290401 INJ 490 2,96)38 5.639.9 Lammmt HRSIPomI Date Anndatlon EDW Mk =SSV: NONE Last Iol 4111/2099 K&GN etl RIP ReIsx DNe 47.50 WIS1998 ID4au. visrzma lDsz&AM Last Tag VetiwlpemassNaD AnnalYbn DeWa 1RKB1 Eno pah WNlaore Last MaE BY HwcER.3B1 e 5,3162312017 10-025A pproven Last Tag: Elin5.0 Last Rev Reason COHOVLTOF; i]6i3t0 TIIBINGIFAK... GAs uFr: AaoSe NIPPLE aa595 LDCATOR45P1.0 Pill 4..a SEALws5Y, Asona RBP:4555.0 WINCOWA:4,RM,"�.0 HMDVCtIOH�Fa}SiA.a an A ,mo mERP;50a W.ta1.0- 5.16D0al IPERFftf II@RF: S.bOQ5yM0� IPERF.ILXE0GMO1 IPERF IMEm oaa. IPERF 53m0,5.3(a.0� IPERF;5.3N.o5.336D� IPERF;5SU.05,Y50- IPERF,533SDSYaA� IPERR o,ass054100- DNER:459,T5, S Annmalon Ene Dab wenRDre lutMoa av Rev Reason Pull straddle Patcbassably and set MPt2d12019 1D -125A jusuonna Casing Strings casino Desenptbn CONDUCTOR OD lmlIDllnl 16 1506 IDPIn(R) s2Deph IRKS) SA re, lrvDl.. WOLan ll... Gane 475 1210 1210 62.58 K40 TOP inure WELDED Eason Dewaptkm PROWCTION-Post Sidetrack OD llnl IDllnl 554 4.95 Top,(RB) Sd OepaWBI Sat 411 4,00 3,2DW1N 1550 L-80 M STEM camrs, aesui,son WINDOWA OD onl IO on) 512 400 TOP(RKO) . DN* 1RKB1 Bet Desoto 1ND).-IMLM (l... Oraae 4.692.0 4,7020 3.185.2 Top nand Cas4p Easonou- LINER 000) I.Aa 31/2 299 TOP(ENo) SM anon Goes) del 0ep[M1 II VDI- wVIm 11... Grade 4,529.] 5.8365 4.0490 9.30 L -0o Res TMS IBT-MOD Liner DetagS Teal1TVD1(BKB) ap IRKS) Top TOPISOPI brawl ID IMnM IIN 4529.7 3,038.9 J348 PACHER BAKER'SABL-3 LINER TOP PACKER 2.]80 VV Tubing Strings TUGnP Desorption Stene Ma... 1011n) Tap IRKS) Bet Depth lR,. 3et DIE.RVO)I.. &111&111 GmM Top tonne>bn TUBING 31/2 2.99 28.1 4529.7 3.038.9 930 L -BO EUEBNMOD Completion Details Top(" Toptacl NmnInal TOP mKB) mKBI (°1 Item Do Com mlln) 28.1 28.1 0.00 1 HANGER VETCO TUBING HANGER 3.500 4,6596 2. 1.1 35.33 NIPPLE CAMCO DS'LANOING NIPPLE 2.81 4.5044 3.017 34.16 LOCATOR BAKER LOCATOR 2.937 Is/1 2.985 6,505.8 3.0190 34.12 PBR BAKER'45-40 SPECIAL CLEARANCE MRw AL 45294 3,0387 3346 BEALABSY MODEL KRK22ANCHOR SEAL ASSEMBLY 2,985 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc-) Top UvD) Top(RKB) MKB) Top no 1°) hs Oom Run Dab IDllnl ]26.0 ]24.6 9.17 TUBING LEAK TUBING LEAN CONFIRMED BY EL 4.555.0 SOQUA 32.75 41/2U200.000 RBP 2.72'P2P RBP CAL 849'(CPP35205) Wl Eeual'Ring 0.000 lva(CPEQ3502S) PATCH 3'SURFACECS13 PATCH down 3'it"Rom stlebead Pertoretlens 8 Slots 1joKB) I iop IRKS) BM1300 IRKBI BMile eh« Dan (SOn ft LD.1 Tnm Dab 1 Type Cam 5.0980 5.130.0 3,5523 3,583.0 3.M V/S D. 1D -125A Sp02000 4.0 WERE iBO DEG PH. 25'HC DP 5,1800 5.1840 3,811.5 3.842.8 VIS B. 1D -125A 5202000 4.0 IPERF 180 DEG PK 25'HC DP 5,210.0 5.234.0 3,857fi 3,6]9.7 WB A4.10. WM2000 4.0 12M IPERF 180 DEG PH, 25' HC DP 5,252.0 5.2600 3,fi96.2 3. Pose W5A3. 16 51302000 40 12M IPERF 180DEGPH2.5"HCDP 5,2700 5,2511.0 3.7127 3,129.3 WSA3,11 51302000 40 125A IPERF 180 DEG PH, 2.V MC DP 5,298.0 5,3040 3,7384 3,]439 Vas A3,16 51302000 4.0 12M IPERF 180 DEG PH, 25"HCDP 5,3240 5.335.0 3,]62.2 3,775.1 WS P2.16 5/302000 4.0 25A IPERF 1800EG PH, 2.5"HCDP 5.350.0 5,3135.0 3.]88.1 3.799.8 WS A2, 1D- 513012000 40 25A WERE 70 DEG PH. 2.5"ML DP 5.375.0 5,3840 3.808.0 3,817.2 MA21D- &292000 4.0 2M IPERF 180 DEG PH. 25' HC DP 5396.0 56105 J828.2 3841.1 VvSA2, 1D- 5/29/2000 40 125A IPERF 180 DEG PH, 2.5 HC DP Notes: General B Safety Eno Date IM�latatlOn NOTE: MONOBOREIN2ECTOR 4111/200009 G1120E:16125 SIDETRAGKEC NO 5124/2009 NO I P:VIEW SCHEMATIC w/Alaska SCRematic6.0 Tubin Spool 2.5# H-40 @ 115' RI 3.5" Tubing Cut @ 60'-90' RKB to allow old tubing to communicate with IA for monitoring. 1D -125A Proposed RWO Completion 1/2" x 2-3/8" Tubing Crossover: i-55' RKB Cemented IA: Mitigates future 5.5" casing collapse. Joints to 15.5# L-80 shoe @ 4 III II @ 4730' RKB 3.5" Liner @ 4529' IF*] RKB to 5636.5' RKB Tubing COMPLETION 3-112" 9.3# L-80 ELIE 8rd 3-1/2" Camco gas lin mandrels DS Landing Nipple Baker 3-1/2" SABL-3 Liner Top Packer xxxx' RKB (3.880" ID) 3-1/2" 9.3# L-80 EUE 8rd New COMPLETION 3-1/2" x 2-3/8" Completion to TD 2-3/8" Expansion Joints 2-3/8" x 3-1/2" Liner Top Packer 2-3/8" Tubing Tail Nipple Profile 13 5/8" 50001 WP NYORIL, WE "CK' r3 5/8" 50001 WP -- WCM£D JO 8Y 13 5/8' FLANC£D 801TOM "NULAR BOP 54 1/1" LENGOI 13-5/8" 50001 F fANCCO NYDR¢ DOUCAi( PRCVFNlOR 58 18 r/8" L(NG(N 3' 50001 NCR VALV£ 7" KrcL urdf 1001 CA(F VAIVE HYORRVL'C RAAf'INQF PSI I? fLANccR. coNN£CnbN J6 ¢NCia WELL LOG TRANSMITTAL #905439807 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Set Record: 1D -125A Run Date: 1/24/2019 2000 4 4 30376 February 13, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D -125A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22904-01 RECEIVED FEB 19 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: OZ/l zo Signed: • • 20 0044 WELL LOG 2 9 2 5 0 RECEIVED PROACTIVE DIAGNOSTIC SERVICES, INC. MAY 1 1 2018 AOGCC To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907)245-8952 SCAMS jun 0 • .82018 1) Caliper Report 09-May-18 1D-125A 1 Report /CD 50-029-22904-01 2) Signed : Date : /7-b Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM DAAchivesNasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx 20 0044 • 29250 1116 Memory Multi-Finger Caliper Col Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-125A Log Date: May 9,2018 Field: West SAK Log No.: 18536 State: Alaska Run No.: 4 API No. 50-029-22904-01 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD-MOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 4,518 Ft.(MD) Pipe Description: 3.5 inch 9.3 lb. IBT-MOD Top Log Interval: 4,518 Ft. (MD) Pipe Use: Liner Bottom Log Interval: 4,567 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of DS Nipple at 4,459.6 feet(Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing and liner logged appears to be in good to poor condition, with a maximum recorded wall penetration of 51%in a line of corrosion in joint 104(3,288 feet). Additional wall penetrations ranging from 20%to 51%wall thickness are recorded in 125 of the 150 joints logged. Recorded damage appears as isolated pitting, a line of pits and broadening into line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The body region analysis and joint tabulation data for the 3.5 inch tubing and liner logged are combined. The caliper recordings indicate slight buckling from surface to—4,500 feet. This is the fourth time a PDS caliper has been run in this well and the 3.5 inch tubing and liner have been logged. A comparison of the current and previous log (June 30, 2009) indicates slight increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by-joint basis between the current and previous log is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : Description Percent Wali Penetration Joint L) utl Line Corrosion 51 104 3,288 Ft. (MD) Line Corrosion 51 78 2,489 Ft. (MD) Line Corrosion 50 91 2,894 Ft. (MD) Line Corrosion 50 115 3,639 Ft. (MD) Corrosion 49 138.3 4,408 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss(>9%)are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing and liner logged. B. DiMatteo, R. Vasquez HY. Yang J. Fama Field Engineer(s) Analyst(s) WItness(es) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • Correlation of Recorded Damage to Borehole Profile • Pipe 1 3.5 in (31.0'-4,567.3') Well: 1D-125A Field: West SAK Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 9, 2018 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 33 10 324 20 639 30 955 40 1,271 50 0 1,587 60 '� 1,903 70 EEl 80 c90 0 AMIE 100 3,162 110 3,475 120 3,790 130 4,105 GLM 1 140 4,467 141 4,538 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=141 • Maximum Recorded Penetration Comparison To Previous Well: 1 D-125A Survey Date: May 9,2018 Field: West SAK Previous Date: June 30,2009 Company: ConocoPhillips Alaska,Inc. Tool Type: UW MFC 24 No.218370 Country: USA Tubing: 3.5"9.3 lb L-80 EUE 8RD-MOD Overlay Difference Maximum Recorded Penetration(mils) Difference in Maximum Penetration(mils) 0 50 100 150 200 250 -200 -150 -100 -50 0 50 100 150 200 0.1 0.1 9 9� 19 193 29 293- 39 39- 49 497 _. 59 . – 59'-c ` L r E 69 - _ E 694 7 79 9 i 89 I — 89 99 993 - i 109 — 109 119 119.1, 129 129.' ami 118 1 138.1' 140.3 '40.3 -23 -17 -11 -6 0 6 11 17 23 II May 9,2018 in June 30,2009 Approximate Corrosion Rate(mpy) Corrosion Rate(mpy) Top 10 Jts. Overall Average 6 1 Median 5 1 • 0 PDS Report Overview C1144S, Body Region Analysis Well: 1 D-125A Survey Date: May 9,2018 Field: West SAK Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Analyst: HY.Yang Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD 2.992 in. 31 ft. 4,518 ft. 3.5 in. 9.3 ppf L-80 IBT-MOD 2.992 in. 4,518 ft. 4,567 ft. Penetration(%wall) Damage Profile(%wall) 100 =NI Penetration body Metal loss body Mill0.O1I F — 50 100 80 -_ 60 OM ..: 40 24 MI .... 20 Mel 0 _ 0 to 20 to 40 to over 49 20% 40% 85% 85% Number of joints analyzed(total= 150) 24 86 40 0 1 74 f Damage Configuration(body) 150 - 100 99 50 0 124 - 1 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 1 (12:00) Number of joints damaged(total= 139) 140.3 — 25 2 112 0 0 Bottom of Survey= 141 • • PDS Report Joint Tabulation Sheet Well: 1 D-125A Survey Date: May 9, 2018 Field: West SAK Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Tubing 2.992 in. 0.254 in. 31 ft. 4,518 ft. 3.5 in. 9.3 ppf L-80 IBT-MOD Liner 2.992 in. 0.254 in. 4,518 ft. 4,567 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 31 0 0.02 9 3 2.90 Pup 1 33 0 0.06 . 25 2 2.90 Isolated Pitting. Slight Buckling. 1.1 65 0 0.04 15 4 2.89 Pup Shallow Line of Pits. ■ 2 71 0 0.02 9 3 2.89 3 102 0 0.05 21 4 2.91 Isolated Pitting. 4 134 0 0.06 22 3 2.92 Isolated Pitting. 5 166 0 0,12 45 2 2.90 Isolated Pitting. 6 197 0 0.04 14 3 2.90 Slight Buckling. 7 229 0 0.09 34 2 2.89 Isolated Pitting. 8 260 0 0.04 14 3 2.87 9 292 0 0.07 27 2 2.91 Isolated Pitting. 10 324 0 0.03 11 3 2.90 ■ 11 355 0 0.05 18 3 2.89 Shallow Pitting. Slight Buckling. ■ 12 387 0 0.02 9 2 2.91 13 418 0 0.02 9 2 2.91 14 450 0 0.02 8 2 2.91 15 482 , 0 0.08 32 3 2.90 Isolated Pitting. ■ 16 513 0 0.07 28 2 2.91 Isolated Pitting. Slight Buckling. 17 545 0 0.09 37 2 2,90 Isolated Pitting. 18 576 0 0.03 13 2 2.92 19 608 0 0.04 14 2 2.91 20 639 0 0.03 13 2 2.91 21 671 0 0.09 35 2 2.91 Isolated Pitting. Slight Buckling. 22 702 0 0.08 30 2 2.90 Isolated Pitting. 23 734 0 0.04 17 3 2.91 Shallow Pitting. 24 766 0 0.05 . 20 2 2.91 Isolated Pitting. 25 797 0 0.05 18 2 2.92 Shallow Line of Pits. 26 829 0 0.09 36 4 2.91 Line of Pits. Slight Buckling. ■ 27 860 0 0.08 33 4 2.92 Line of Pits. ■ 28 892 0 0.07 28 3 2.91 Line of Pits. 29 923 0 0.09 37 4 2.90 Line of Pits. ■ 30 955 0 0.08 33 4 2.92 Line of Pits. ■ 31 987 0 0.09 36 3 2.90 Line of Pits.Slight Buckling. ■ 32 1018 0 0.09 36 3 2.91 Line of Pits. ■ 33 1050 0 0.10 37 4 2.90 Line of Pits. 34 1081 0 0.08 32 4 2.91 Line of Pits. ■ 35 1113 0 0.08 31 2 2.92 Line of Pits. 36 1144 0 0.05 20 2 2.92 Line of Pits. Slight Buckling. 37 1176 0 0.06 24 2 2.90 Isolated Pitting. 38 1208 0 0.06 23 2 2.92 Line of Pits. 39 1239 0 0.05 21 3 2.91 Line of Pits. 40 1271 0 0.05 20 3 2.90 Isolated Pitting. 41 1302 0 0.05 18 2 2.90 Shallow Line of Pits.Slight Buckling. 42 1334 0 0,05 20 2 2.89 Isolated Pitting. 43 1366 0 0.05 19 3 2.89 Shallow Pitting. 44 1397 0 0,07 26 2 2.90 Isolated Pitting. 45 1429 0 0.04 16 2 2.91 Shallow Line of Pits. 46 1460 0 0.06 22 3 2.90 Line of Pits. Slight Buckling. 47 1492 0 0.05 18 2 2.92 Shallow Pitting. 48 1524 0 0.04 17 4 2.91 Shallow Pitting. Penetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet \-arr'351 Well: 1D-125A Survey Date: May 9, 2018 Field: West SAK Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Tubing 2.992 in. 0.254 in. 31 ft. 4,518 ft. 3.5 in. 9.3 ppf L-80 IBT-MOD Liner 2.992 in. 0.254 in. 4,518 ft. 4,567 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 49 1555 0 0.04 16 2 2.90 Shallow Pitting. ■ 50 1587 0 0.05 21 3 2.91 Isolated Pitting. 51 1618 0 0.04 15 2 2.88 Shallow Pitting. Slight Buckling. ■ 52 1650 0 0.04 17 3 2.91 Shallow Line of Pits. ■ 53 1681 0 0.05 19 3 2.91 Shallow Line of Pits. 54 1713 0 0.08 33 2 2.91 Isolated Pitting. ■■■ 55 1745 0 0.10 38 2 2.91 Line Corrosion. ■ 56 1776 0 0.06 25 3 2.92 Line Corrosion. Slight Buckling. ■ 57 1808 0 0,07 28 6 2.91 Line Corrosion. .■ 58 1839 0 0.06 25 4 2.90 Line Corrosion. �■ 59 1871 0 0.09 35 3 2.90 Line Corrosion. ■■ 60 1903 0 0.07 29 3 2.90 Line Corrosion. ■ 61 1933 0 0.08 30 3 2.90 Line Corrosion. Slight Buckling. ■■i 62 1965 0 0.09 35 3 2.92 Line Corrosion. M■ 63 1997 0 0.09 36 3 2.91 Line Corrosion. ■■ 64 2028 0 0.11 41 3 2.90 Line Corrosion. 65 2059 0 0.07 29 3 2.90 Line Corrosion. ■■: 66 2091 0 0.11 44 3 2.89 Line Corrosion. Slight Buckling. ■■ 67 2122 0 0.09 33 3 2.89 Line Corrosion. ■■■ 68 2154 0 0.08 30 3 2.91 Line Corrosion. ■Ir 69 2185 0 0.09 37 3 2.91 Line Corrosion. ■■■ 70 2217 0.04 0.11 41 3 2.90 Line Corrosion. ■■■ 71 2249 0 0.11 42 4 2.88 Line Corrosion.Slight Buckling. .■■ 72 2280 0 0.09 36 4 2.91 Line Corrosion. ■■■ 73 2312 0 0.09 35 3 2.90 Line Corrosion. ■■■ 74 2343 0 0.10 39 4 2.92 Line Corrosion. l■■ 75 2375 0.05 0.09 34 4 2.90 Line Corrosion. m■■ 76 2407 0 0.11 41 4 2.91 Line Corrosion. Slight Buckling. ■■ 77 2438 0 0.11 42 4 2.90 Line Corrosion. ■■ 78 2470 0 0,13 51 4 2.90 Line Corrosion. ■■ 79 2502 0.04 0.11 45 4 2.89 Line Corrosion. ■■ 80 2534 0.04 0.09 36 3 2.89 Line Corrosion. ■■ 81 2565 0.05 0.09 37 4 2.90 Line Corrosion.Slight Buckling. ■■ 82 2597 0 0.09 37 4 2.90 Line Corrosion. g■■ 83 2628 0 0.09 . 33 3 2.90 Line Corrosion. mom 84 2659 0 0.08 30 3 2.90 Line Corrosion. ■■o 85 2691 0.08 0.12 46 4 2.90 Line Corrosion. e■■ 86 2722 0.09 0.10 41 5 2.92 Line Corrosion. Slight Buckling. ■■ 87 2754 0.06 0.10 41 4 2.90 Line Corrosion. ■■ 88 2786 0.09 0.11 43 5 2.91 Line Corrosion. ■■ 89 2817 0.05 0.10 39 4 2.90 Line Corrosion. n■■ 90 2849 0.06 0.09 37 4 2.90 Line Corrosion. ■■ 91 2880 0.05 0.13 50 5 2.92 Line Corrosion. Slight Buckling. n■■ 92 2912 0.05 0.10 37 4 2.90 Line Corrosion. m■■ 93 2944 0.08 0.12 47 4 2.90 Line Corrosion. ■■ 94 2975 0 0.11 41 4 2.90 Line Corrosion. ■■ 95 3005 0.06 0.10 39 5 2.91 Line Corrosion. ■■ 96 3036 0.06 0.09 36 5 2.90 Line Corrosion. Slight Buckling. ■■ 97 3068 0.04 0.09 37 5 2.90 Line Corrosion. ■■ 98 3100 0 0.10 40 4 2.91 Line Corrosion. Penetration Body Metal Loss Body Page 2 I 110 PDS Report Joint Tabulation Sheet Well: 1D-125A Survey Date: May 9, 2018 Field: West SAK Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Tubing 2.992 in. 0.254 in. 31 ft. 4,518 ft. 3.5 in. 9.3 ppf L-80 IBT-MOD Liner 2.992 in. 0.254 in. 4,518 ft. 4,567 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 99 3131 0.08 0.10 39 4 2.89 Line Corrosion. -. 100 3162 0 0.12 46 3 2.90 Line Corrosion. 101 3194 0.07 0.11 43 4 2.91 Line Corrosion. Slight Buckling. now 102 3224 0.08 0.09 36 4 2.91 Line Corrosion. Elm 103 3255 0.05 0.11 43 4 2.91 Line Corrosion. 104 3287 0.05 0.13 51 5 2.89 Line Corrosion. 105 3318 0.06 0.12 48 5 2.90 Line Corrosion. a. 106 3350 0 0.12 46 5 2.91 Line Corrosion. Slight Buckling. 107 3381 0.07 0.10 38 4 2.92 Line Corrosion. m. 108 3413 0.07 0.10 38 4 2.90 Line Corrosion. ... 109 3443 0 0.10 39 4 2.91 Line Corrosion. 110 3475 0 0.12 46 6 2.89 Line Corrosion. a. 111 3506 0.08 0.12 46 5 2.90 Line Corrosion.Slight Buckling. on 112 3538 0 0.10 39 5 2.90 Line Corrosion. -- 113 3570 0.08 0.10 37 4 2.91 Line Corrosion, .� 114 3601 0.05 0.10 39 4 2.91 Line Corrosion. •tea 115 3633 0.05 0.13 50 5 2.89 Line Corrosion. -. 116 3664 0 0.11 43 6 2.91 Line Corrosion. Slight Buckling. 117 3696 0.05 . 0.12 . 47 4 2.90 Line Corrosion. -. 118 3728 0.08 0.10 40 5 2.90 Line Corrosion. .� 119 3759 0.07 0.11 41 5 2.89 Line Corrosion. .. 120 3790 0.05 0.10 39 6 2.91 Line Corrosion. ta. 121 3822 0.05 0.10 39 5 2.90 Line Corrosion. Slight Buckling. . 122 3853 0.04 0.10 38 6 2.89 Line Corrosion. nu 123 3885 0.07 0.10 38 6 2.88 Line Corrosion. •• 124 3917 0.06 0.10 39 4 2.90 Line Corrosion. -- 125 3948 0.05 0.10 41 5 2.89 Line Corrosion. . 126 3980 0.07 0.09 35 5 2.88 Line Corrosion. Slight Buckling. -- 127 4010 0.06 0.09 36 5 2.87 Line Corrosion. -- 128 4042 0.06 0.09 37 5 2.91 Line Corrosion. .. 129 4073 0.08 0.10 39 6 2.90 Line Corrosion. Amo 130 4105 0.08 0.10 37 5 2.90 Line Corrosion. 131 4137 0 0.12 46 5 2.90 Line Corrosion. Slight Buckling. 132 4168 0,04 0.09 37 5 2.90 Line Corrosion. moo 133 4200 0.05 0.10 40 5 2.90 Line Corrosion. moo 134 4231 0.08 0.10 37 6 2.90 Line Corrosion. u..,,. 135 4262 0.05 0.11 44 6 2.92 Line Corrosion. .u. 136 4293 0 0.10 37 4 2.91 Line Corrosion. Slight Buckling. mow 137 4325 0 0.09 37 6 2.90 Line Corrosion. MIN 138 4357 0.09 0.10 40 7 2.89 Line Corrosion. p.. 138.1 4387 0.05 0.10 40 5 2.91 Pup Corrosion. 138.2 4401 0 0 0 0 2.88 GLM 1 (LATCH @ 12:00) 138.3 4407 0.07 0.13 49 4 2.92 Pup Corrosion. inuo 139 4422 0.09 0.11 45 9 2.91 Line Corrosion. min 139.1 4454 0 0.09 36 4 2.88 Pup Line Corrosion. 139.2 4460 0 0 0 0 2.86 CAMCO DS-NIPPLE 139.3 4461 0 0.09 35 6 2.87 Pup Line Corrosion. maw 140 4467 0.06 0.10 39 6 2.91 Line Corrosion.Slight Buckling. own 140.1 4498 0 0.11 42 4 2.90 Pup Line of Pits. 140.2 4504 0 0 0 0 2,77 BAKER LOCATOR,PBR,SEAL ASSEMBLYI Penetration Body Metal Loss Body Page 3 • • PDS Report Joint Tabulation Sheet Well: 1 D-125A Survey Date: May 9, 2018 Field: West SAK Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Tubing 2.992 in. 0.254 in. 31 ft. 4,518 ft. 3.5 in. 9.3 ppf L-80 IBT-MOD Liner 2.992 in. 0.254 in. 4,518 ft. 4,567 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 140.3 4518 0.04 0.10 40 6 2.89 Pup Line Corrosion. 140.4 4528 0 0 0 0 2.77 PACKER 140.5 4534 0.04 0.09 34 5 2.87 Pup Line of Pits. 141 4538 0.09 0.10 39 5 2.92 Line Corrosion. IPenetration Body Metal Loss Body Page 4 • • (a. PDS Report Cross Sections Well: 1D-125A Survey Date: May 9,2018 Field: West SAK Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Analyst: HY.Yang Cross Section for Joint 104 at depth 3,288.310 ft. Tool speed=51 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=62° 1 Finger= 10 Penetration=0.130 in. Line Corrosion 0.13 in.=51%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: 1D-125A Survey Date: May 9,2018 Field: West SAK Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD-MOD Analyst: HY.Yang Cross Section for Joint 78 at depth 2,489.470 ft. Tool speed=50 Nominal ID=2.992 Nominal OD=3.5 _ _ Remaining wall area=96% Tool deviation=62° 1 Finger= 1 Penetration=0.129 in. Line Corrosion 0.13 in.= 51%Wall Penetration HIGH SIDE=UP • • ISI KUP INJ 1D-125A Conac+oPhillips IIP Well Attributes Max Angle a Mb TO Alaska,Inc. Wellborn APVIAMI Field Non. Wellborn awn. Inc11'I MDIttKei Actabn l6Kn ,rnioccTionntips 500292290401 Iti.E.SI SAK NJ 64.90 2,9117.38 5,639.0 --- Commmt 626199111 0.5. Annotation end D.5. Kt-0b eh Rig OWN.Data 10-128812.80172324E .v SSSV:NONE L01t WO: 4/11/2000 47.50 8/12/1998 YMaalotMmaglwR.:1 I Annotation owe, KS{ End Db Annotation /6Last Mod as End Oat. - Last Tag:Enna 5,315.0 6/23/2017 Rev Reason:TUBING LEAK©728 PPlaven 12/4/2017 NANOeS 2a 1-4' ' T I Casing Strings Casing D..crblion m On) 10(In) Top IM1K94 Set Depth 10K04 Set DePth 101401... 1001.0 11...Orale Ton Threat f CCIND0CTOR 16 15.062 4:.5 121.0 121.0 62.58 H-40 WELDED �4-� Casing D�eflptbn CO lin! ID fin) Top 16KHI Sat moth 111121 Set Depth 17/21...9(1dl 11,58 Wade Top Throb PRODUCTION-Post 5.54 4.950 41.1 4,730,0 3,211,0 15.501-80 BTCM 7 Sidetrack O (:ring eserbdon CO Iinl IO INI Top Ihl(tf Sot Depth 16K91 Sal Depth IND/...MlgLsal 9...Oracle Top Thread WINDOW 51/2 4.000 4.692.0 4.702.0 3,186,2 Gabe Owcrlptbn COON 10 Orli Top 06631 S.Depth 01K134 341 booth 411/03... Wt/t41111...Orads Top Thread I.INF.R 3 112 2,992 4.529.7 5.636.5 4,040.0 9,301.-en IR1-MOD ^^`coi_UCTOR 41.9.191.' +' Liner Details 1111 Hominid ID TIMING 19801:7290 lop IttK61 TOP 171401 IttI(el Tap Incl l'1 Ileo On m Colint 4,520.7 3,030.9 33.46 PACKER BAKER SAM.-3 LINER TOP PACKER 2.780 Tubing Strings Tubing Description String Mo...ID Ilnl TOP I6Kti SH 17.90516..{32 Dap.,Ira)/1,..Wt IO/M1I Orale Top Connection TUBING 3112 2.992 28.1 4,52971 3.038.9 9.30180 EUEBrdAAOD Completion Details 500110.110 OAS 195744009 3 Top 119(04 Top ITV04 rout' Top Incl!'! Sem 005 Cam 11.1 28.1 28.1 0.00 HANGER VETC07UBNG HANGER 3.500 4.459,8 2,981.1 35.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2812 4,604.4 3,017.9 34.18 LOCATOR BAKER LOCATOR 2.937 4,506.8 3,019.0 34.12 PBR BAKER"4540 SPECIAL CLEARANCE PBR w/10' 2.985 .-:._t.+•... SEALS 4,529 4 3,036 7 33.46 SEAL ASSY MODEL KBH-22-ANCHOR SE Al A.SSEMBI.Y 2985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top411403 Top Il1I Top IhKBl 151,01 I'1 Or Com Ron Date 10 11111 .ocer00:48.4 1 726,0 724.6 017 TUBNG TUBING LEAK CONFIRMED BY EL-LDL 11/25/2017 '4.:latl LEAK 4,54100 3,081.2 32.07 PLUG-WRP 3.5'SC-WRP(2.43"OAL) 10/29/2017 0.139 681:44060 4 1 PATCH 3-SURFACE CSG PATCH down 3'11'from Made,' 5/25/2009 head SEAL ASSY.4.526.4 Perinfations 8 Slots a_L. snot o Owns Top(TVO) atm(!1404 1910061 T4128801) 915(1»(9) (16/0) (Ma) Lana Dob t! TTp0 Com 6,098.0 5,130.0 3.562.3 3,583.8 WS O,1D- 5/30/2000 4.0 IPERF 160 DEG PH,26'HC 125A DP •:u0-Who 4 280 0 01 5,180.0 5,194.0 3,611.5 3,642.9 WS B,16 5/30/2000 4.0 IPERF '180 DEG PH,2.5'HC 125A OP • 5,210.0 5,234.0 3,6576 3.879.7 WS 84,16 5/30/2000 4.0 IPERF 180 DEG PH.2.S'HC VJWDOWA 4492 a-47020 125A DP 0110114 C105-nisi scsraha t 9,252.0 5,260.0 3,6962 3,703.6 WS A3,16 5/30/2000 4.0 IPERF '180 DEG PH,2,6'HC 41+41100- . 125A DP 5,270.0 8288.0 3.712.7 3,729.3 WS A3,10. 5/30/2000 4.0 IPERF '180 DEG PH,2.5'HO 125A DP 5,298.0 5,304.0 3,7384 3,743,9 WS A3,16 5/30/2000 4.0 IPERF '180 DEG PH,2.5"HO .0191 50860-01300 125*, 00 5.324.0 5,338.0 3,7622 3,775,1 WS A2,16 5/30/2000 4.0 IPERF 180 DEG PH.2.5'HC 125A DP ,-- PEA 1.0.1800-8 1940 5.350,0 5,385.0 3,786.1 3,799.8 WS A2,1D- 5/30/2000 4,0 IPERF 180 DEC PH,2.5'HC .. 125A DP 5,375.0' 5,384.0 3,809.0 3,817.2 WS A2,16 5129/2000 4.0 IPERF 180 DEG PH.2.5-HC Pel P.0.2100-82140 .. 125A DP 5,396.0 5,410.0 3,8282 3,841.1 WS A2,16 5/25/2000 4.0 IPERF 180 DEG PH,2.5'HC •` 125A DP PIMP,5202.0-02000 Notes:General&Safety - -. eta Dab Anmhel,,n 51816.8.2700-43000 4/11/2000 NOTE:MONOBORE INJECTOR 4/11/2009 NOTE:1D-125 SIDETRACKED IPERF,62010-4.2040 5/24/2005 NOTE:VIEW SCHEMATIC we/Alaska Sdamat109.0 01/0F.5024942300 _ - PEN a.5 4 2900308.0 Pal6.5570043040 Wr,5%a0-a4100 J Pa ❑5194S207-1416 5---1 • a) 1., F- 1 .- p r r . . . . . . 00 X �O v 1:9><- _c;) > 0' 3 /� Z wr¢ - a, 0 CA ro' 00cll0. c0 0 r� NN Z 0(1 > 1' v —)Cr,CO 4CNrrrrrrr CO N O > � , CO NCIJ aaaa c c ' o s �_ D Y -0 0 di r+o O -5a) a (0 7 u E a a m Q 0 > > > > > > > > E o 0 0 0 0 0 0 0 0 a -1 Z Z Z Z Z Z Z Zc c QJ N 1— t0 t0 00 T O O N to O D C N Z. Q N N N N u "6 @ 0 O u .. u c0O CO a) MS N U J J J J J J J J 0.0C w O � }} wwwwwwww a � � — 1- LL LL LL LL LL LL LL LL � aJ a1 Q1 '0 0 ` Q J J J J J J J J a _0 > 4 QJ LIQ F' Q Q Q Q Q Q Q Q 'Q) N c 0 co O Z Z Z Z Z Z Z Z u (0 N 0 a1 •od LL LL LL LL LL LL LL LL CC .Q C > 1E co cu > O } v o a u U o z E a a, u ' rd, 0 c 0 - - ro s z O U — G ,G ~a c ~ C uO o o a O o aN �' o ` a) o 'Cf 0 _ m m0 a. F- 0 o U c w v 0 C4 V co '' v ro co o C4 0 h z ax to cosW o co (s — d J J J J J J J J 1 d co w 2 3 3 3 3 3 3 3 3 Lu �' L wixceix � ce � � 1:9 Ili w w w w w w w W > > > > > > > > z Y Y Y Y Y Y Y Y ❑ > > > > > > > > J d' < < < d' < < < v W Q Q Q Q Q Q Q Q LL d LL LL LL LL LL LL LL . 0 }' a W DDDDDDD Y Y Y Y Y Y Y Y c U o< X - (V 0 P t` t0 f` 00 N CO CO fC6 ❑ 0 0 0 C W 00 /R O . . . . . . . . QJ V nt c t; r, r, r r; -) to toO > O co 0o co 0 00 -, o o > E 2 2 2 2 n to N — u W w ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ _c X N V @ tv CCE Y 0 O @ 0 O O 0 0 0 O N u <D O O O O O O O O Q V a •00 11") 00 N 0 7 Y : v1 00 00 CO 00 N 0 0 Y Q N N N CO N O M 0) O = •- N N N N N N N N N H t LE np N N N N N O N N C 0 (0 Q) O O O O O r O O L UO O U O O O O O O O O i+ Y C o 00 C N N N N N N N N a -0 O C 02E5 01 w u O = Zm E k"t ,, a) oD a w Y o *,.W: d' to 0 Z Y a/ O Q a- a O r1— CONN to to ,+4. C m r» Z r r r 9.) c .- -0 vii Y c a Q n^i W 2 = _ - M o a C Z y 0 0 • r .�° v to ,_1 u@m E d E E 0 C/9 a t Q H a s 10- 10- • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, October 23, 2017 11:15 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU WSAK 1D-125 (PTD#200-044) Report of suspect IA pressure increase Attachments: 1D-125A.pdf; 1D-125 90 day TIO trend 10-23-17.JPG Chris, KRU WSAK water injector 1D-125A(PTD#200-044)was reported for suspect IA pressure today. Operations attempted to bleed the IA pressure down, but it re-pressured rapidly. The well has been shut in and freeze protected. The plan is for DHD to perform initial diagnostics to include an MIT-IA and pack off tests. The well will be secured as soon as possible although both the diagnostics and secure will be delayed due to the proximity of the Doyon 14. Dependent upon results of the diagnostics and secure any required paperwork will be submitted once a path forward has been determined. Attached is a wellbore schematic and 90 day TIO trend. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AWELLS TEAM sc le : B 2 1 ?,a Cps 1 • o�w . v Oo0 aa) ri ONz _ nn �_'-J IIII •" co a� JrV u I-- Y x C co t ar_ O O 0 - - N O O 0 C C C 0 Z op H T 0 Z V' V' T- (t ' O a o O. C -O O •O -6 W (6 C) (O T Q < Y (o V p li (W7 co to co O Y Ou v -C m N -� la- O c c c v, a) CC .I--, rro -1 ~ N N N O c N v Q H Z; 1 O Ou 'O E O . CC ii MN u is 0000 W J J J J C CL W W_ W_ IL E - O F LL LL LL LL N Q J J J J is -0 y0 ra C U) 1- Q Q Q Q .� vi -0 a-, 00 c) O Z Z_ Z Z aui ra v 0 v • !oil LL LL LL LL .Y� O O . r� co 1-3y u N N O O O O_ co +-' -0 „ U 01 zo i v v a; a, .. 0 a c n3 C . O V Ft. J < CU -E U > td 0 ., LLLL b y O m O m r Ce v C E m a o y z .`o a v W oo U '.. j (..) J ro co tel . c _ 's z • re,0 0ai ., o zaM W033331-1 IV) t.000r ..,IT I W ,. CU on Ll www W > z Y Y Y _3 cecerewa u is "' Q Q Q Q n (n LL m n D = Y 9 N Y Y Y Y a Uil CO X N 0 O W T t0 N u N f % cc p 3 3 u> o co gr 0 0 0 _ minlo 1[J (� O o 0 0 0 i O V v_ t U U U 0 E a rp o d J I> O O C9 ) 7p l tau D O D U 03 BS —•' N K C �° u 0 o o v cDr. 0 0 0 0 rar O rD Na) ,.:.10 , r to O 'u O n N N N L L . a N N N N O .0 r n 3 Q Cf O O 6 Vt . N N N N GJ Q1 O O O O O O O O 3 N N In in a-, O 4% O u C C. co c 11 cov CLD i„ce Ln co int l—z Q1crl E u W CL. 'C. CO d To rr� N �,y N N O p O t' ✓1 �p gpp7� pdp t.,1 O N N N E �•r w7 (U n m z .. az U .. N J N 6 of �f �G C �r. _ a Q LO W C c ro v, 3 co L v •• IA a aQ Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) [] Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] ...C--Dior items: [] Diskettes, No, [] Maps' ~'/'/Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) © Other: [] Logs of various kinds TOTAL PAGES' NOTES' ORGANIZED BY: BEVERLY BR HERYL MARIA LOWELL [] Other By Date: Scanned (done) SCANNED BY: BEVERLY BREN VINC~RIA ReScanned (done) LOWELl RESCANNEDBYi BEVERLY BREN VINCENT SHERYL M,~RtA LOWELL DATE: IS! General Notes or Comments about this file: PAGES: Quality Checked (dooel Rev 1NOTSoanned.wpd • MEMORANDUM TO: Jim Regg Q~l Z(2,~C,~% P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]D-125A KUPARUK RIV U WSAK 1D-125A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~1 ~- Comm Well Name: KUPARUK RIV U WSAK ID-125 Insp Num: mitRCN100718142620 Rel Insp Num: API Well Number: 50-029-22904-01-00 Permit Number: 200-044-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wei ID-i2sA Type Inj. ~. N VD 3039 ~ IA 20 1770 ~ 1700 ]670 ~ P D zoooaao TypeTest SPT Test psi »~o OA InteYVal4YRTST p~F P ~ Tubing 725 825 825 825 Notes: ~ ~,1 ~~ r~ l C'~ -~ I ~CZ~s~ Thursday, July 22, 2010 Page 1 of 1 u MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~~ ~~~Z~~ FROM: Chuck Scheve Petroleum Inspector . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July Ol, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-125A KUPARLJK RIV U WSAK ID-125A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv I/'~ Comm Well Name: KUP~tuK R~v u wsaic 1D-125,q API Well Number: 50-029-22904-01-00 A Insp Num: mitCS090630094316 Permit Number: 200-044-0 ~ Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 6/27/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 1D-125A Type Inj. I~' ~j'~ 3039 ~ jA 260 2020 ~ 1960 1960 P.T.D Zoooaao TypeTest SPT Test psi ~ soo OA Interval oT~x p~ P ~ Tubing iooo iooo iooo iooo NOtes• Test performed post casing patch. ~ i} e ": 1 j( Rf r1r~r~`i, "<i .~c ,.. . " `, :.F 4, ~ . _ r l ~ C., ..f Wednesday, July O1, 2009 Page 1 of 1 • ~~ ~ ~~~~~ C~ -ro: Aoc~cc Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT] 7he technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, inc. Attn: Robert A. Richey 130 West Internatianal Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) Cafiper Report 2] Signed Print Name: 30zJem-09 1 D-125A 1 Repor~ / EDE 50-029-22904Q1 v~~ a«~ -o~~-/ l ~ a~~ r,-~':~~~°~ ~UL = ~ 2GG-9 / ;~'/ '~ Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONA! AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (90~)245-88952 ~-OMIL : ;:__ __,... _ _ __~ _~_ .__ - --- - YVEBSITE . _ _~ :~ _______ ,_ __ . __.. ~ C:~Documen~s and Settingsl0wnerlDesktoptTrans,mit_Conoco.docx ~ ' • • Memory Mutti-Finger c~r~p~~ S Log Results Summary Company: ConocoPhillipsAlaska,lnc. Welt: 1D-125A Log Date: June 30, 2009 Field: West Sak Log No. _ 7340 State: Alaska Run No.: 2(MIT) API No.: 50-029-22904-01 Pipe1 Desc.: 3.5" 9.3 Ib. L-8p EUE 8RD-MOD Top Log Intv11.: 29 Ft. (MD) Pipe1 Use: Tubing and Liner Bot. Log Intvl1.: 4,633 Ft. (MD) , Inspection Type : Corrosive & Mechanical Damage lnspection 1 COMMENTS : This ca/iper data is tieaf into the DS Nipple @ 4,~so` (~iiqer's Depth). , This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and liner logged are in good to poor condition, with a maximum recorded wall penetration of 50°1o recorded in an area of corrosion in joint 139 (4,473'). Wall penetrations from 20°~ to 47% walt thickness are recorded in 107 of the 151 joints logged. Recorded ' damage appears as a line of pits from ~830' to --1,350', a line of corrosion from -1,750' #o -3.450', and general corrosion from -3,450' to --4,520'. No significant areas of cross-sectional wall loss or I.D. restt'ickiot~s are recorded throughout the tubing and liner logged. , The caliper recordings indicate slight buckling from ~1,800' to --4,500'. This is the second time a PDS caliper has been run in tfiis well and the 3.5" tubing and liner have been logged. A comparison of the current and previous log (July 31, 2005) indicates fittle, if any increase in ' corrosive damage during the time bEtween logs. A graph illustrating the difference in maximum recarded penetrations on a joint-by joint basis between the current and previous iog is inctuded in this report. 3.5" TUBING 8~ LINER - MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 50%) Jt. 139 c~ 4,473 Ft. (MD) Line corrosion ( 47%) Jt. 105 @ 3,356 Ft. (MD) Line corrosion ( 46%) Jt. 88 ~ 2,811 ~t. (MD} Line corrosion ( 46°l0) Jt. 104 ~ 3,337 Ft. (MD) Corrasion ( 46%) Jt. 130 ~ 4,150 Ft. (MD) 3.5" TUBING & LfNER - MAXIMUM RECORDED CROSS-SECTIONAL METAL I.OSS: No significant areas of cross-sectional waU loss (> 9%) are recorded throughout tMe tubi ng and liner logged. 3.5" TUBIWG 8~ LINER - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: Wm. McCrossan Anal st: C. Wa/drop Witness: C. Fittpatrick ProACtive Diagnostic Services, Inc. ; P.O. B~x 1369, Stafford, TX i7497 Phone: (281) or (888) 565-9085 Fax; (231) 565-1369 E-mai1: PDS~a~memorylog.com Pi~udhoe Bay Field Office Phone: (407} 659-2307 Fax: (907) 659-2314 ~ c> ~ C~ ~W -o`-~G~ r ~S~~S • ~ Correlation of Recorded Dama e to Borehole Profile g ~ Pipe 1 3.5 in (47.5' - 4623.5') Well: 1 D-125A Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 30, 2009 . A pprox. Tool De viation ^ A pprox. Borehol e Profil e 50 340 657 973 1291 1607 1922 2237 ~ ~ 2554 ~ 2870 ~ ~ 3183 3496 3811 4126 GLM 1 4487 143 4624 0 5 0 1 00 Damage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 143 1 10 ` 20 30 ` __ ~ ` ~ 40 ~ , ~ ~ 50 ~ ~ 60 „ 70 I e, ` ~ ( ~ 80 Z ( c 90 'o 100 110 120 130 i I ~ i 140 I I ( I I • s ~ ~ Maximum Recorded Penetration ,:--R Comparison To Previous Well: 1D-125A Survey Date: June 30, 2009 Field: West Sak Prev. Date: July 31, 2005 Company. ConocoPhillips Alaska, Inc. Tod: UW MFC 24 Na 218370 Country: USA l ubing: 3.5" 93 Ib L-80 EUE BRD-MOD Overla Max. Rec. Pen. (mils) 0 50 100 150 200 250 o. ~ 9 19 29 39 49 _. ~ i 59 ~ 69 E - z c ~~ 'o 89 99 109 719 - 129 138 140 ^)une 30, 2009 ~ July 31, 2005 Difference -1 D 00 -5 iff. in Ma~c 0 0 . Pen. (mils 5 ) 0 1 00 a~ E ~ z c 0 -2 6 -1 3 0 1 3 2 6 App rox. Corros ion Rate ( mpy) 9 1 s 29 - - 39 49 59 69 79 - 89 99" 109 119 129 _ 138 ~ 140 i • ~ PDS Report Overview ~~, s . Body Region Analysis Well: 1 D-125A Survey Date: )une 30, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop _ Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 151 pene. 0 5 37 88 21 0 loss 15 136 0 0 0 0 Damage Configuration ( body ) 60 40 - -- 20 0 ---- isolateJ g~~neral line nng hole~poss pitting corcosion corrosion cortosion ible hole Number of'oints dama ed total = 117 22 38 57 0 0 Damage Pr~le (%wall) ~ penetra6on body ~ metal loss body 0 50 100 n GLM 1 Bottom of Survey = 143 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEEf Pipe: 3.5 in 93 ppf L-80 EUE 8RD-MOD Well: 1 D-125A Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 30, 2009 Joint Jt. Depth I'c~n. Pen. Pen. I Metal I Min. Da mage Profile No. (Ft.) l 1~>~<~t Body /~ I_oss I.D. Comments (/o wall} (In~.) (Ins.) °i~> (Ins.) 0 50 100I, .1 47 0 0.01 4 2 2.90 PUP 1 50 U 0.03 13 1 2.91 1.1 81 0 0.01 6 2 2.92 _ PUP 2 87 tl 0.03 11 2 2.91 3 119 0 0.03 10 1 2.91 4 150 t) 0.03 11 2 2.92 5 182 0 0.03 11 1 2.90 6 214 0 0.04 18 7 2.92 7 245 ll 0.03 13 1 2.88 8 277 U 0.02 9 1 2.88 9 309 0 0.04 14 2 2.92 10 340 (1 0.03 11 1 2.91 11 372 0 0.03 13 1 2.91 12 404 0 0.03 13 5 2.91 13 435 O 0.03 11 1 2.91 14 467 l) 0.03 12 1 2.91 15 499 O 0.04 17 2 2.91 16 531 ll 0.03 12 2 2.92 17 562 0 0.05 20 3 2.91 Isolated ittin . 7 8 594 0 0.02 9 ~ 2.92 19 625 0 0.03 11 3 2.91 20 657 0 0.03 13 1 2.92 21 689 O 0.03 12 3 2.91 22 720 O 0.05 19 2 2.92 Isolated ittin . 23 752 U 0.04 17 2 2.92 24 783 0 0.04 17 3 2.91 __ 25 815 0 0.05 18 3 292 Line of its. 26 846 0 0.10 38 3 2.91 Line of its. 27 878 U 0.08 31 2 2.92 Line of its. 28 910 O 0.07 28 2 2.92 Line of its. 29 941 0 0.09 35 Z 2.91 Line of its. 30 973 U 0.09 34 4 2.93 Line of its. 31 1005 ~) 0.07 29 6 2.91 Line of its. 32 1036 l) 0.08 33 3 2.92 Line of its. 33 1068 l) 0.08 32 2 2.90 Line of its. 34 1100 0 0.08 33 2 2.92 Line of its. 35 1132 0 0.10 39 2 2.92 Line of its. 36 1163 0 0.05 19 1 2.92 Line of its. 37 1195 0 0.04 14 2 2.91 38 1227 0 0.06 22 1 2.91 Line of its. 39 1259 U 0.07 Z7 4 2.91 Line of its. 40 1291 ~1 0.05 21 2 2.90 Line of its. 41 1322 t) 0.05 20 2 2.91 Line of its. 42 1354 cl 0.04 17 Z 2.90 43 1386 (1 0.04 17 1 2.89 44 1417 l) 0.05 19 2 2.90 Isolated ittin . 45 1449 l~ 0.04 14 2 2.91 46 1480 l~ 0.06 22 2 2.91 Isolated ~ittin . 47 1512 l) 0.04 17 3 2.91 48 1543 0 0.04 17 5 2.92 _ Lt~De~x~sits. Penetration Body Metal Loss Body Page 1 PDS•ORT OINTTABULATION S~Ef 1 Pipe: 3.5 in 93 ppf L-$0 EUE 8RD-MOD Well: 1 D-125A Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocaPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: )une 30, 2009 joint No. Jt. Depth (Ft.) I'c~n. IIF~.c~t (In,.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1575 (1 0.04 16 3 2.91 50 1607 l) 0.04 14 2 2.92 51 1638 0 0.05 19 1 2.90 Isolated ittin . 52 1670 (1 0.04 17 1 2.91 53 1701 0 0.03 13 2 2.91 54 1733 0 0.05 20 2 2.91 Line corrosion. 55 1764 0 0.06 22 2 2.92 Line corrosion. 56 1796 ll 0.06 24 2 2.93 Line corrosion. Sli ht ucklin 57 1828 0 0.07 26 9 2.91 Line corros'on. 58 1859 U 0.07 26 2 2.90 Line corrosion. 59 1891 0 0.08 31 3 2.89 Line corrosion. 60 1922 0 0.07 27 2 2.91 Line corrosion. 61 1954 (1 0.06 24 2 2.92 Line corrosion. 62 1985 0 0.09 35 4 2.92 Line corrosion. 63 2017 0 0.08 31 3 2.91 Line corrosion. Slight BucklinR. 64 2048 0 0.06 24 3 2.91 Line_corrosion. 65 2079 O 0.07 26 3 2.90 Line corrosion. 66 21 11 0 0.08 33 3 2.91 Line corrosion. 67 2142 ll 0.07 28 2 2.90 Line corrosion. 68 2174 0 0.07 29 2 2.91 Line corrosion. 69 2205 0 0.10 40 4 2.91 Line corrosion. 70 2237 0.07 0.11 42 2 2.91 Line corrosion. Sli ht Bucklin . 71 2269 0 0.10 39 2 2.89 Line corrosion. 72 2300 0 0.07 26 3 2.91 Line corrosion. 73 2332 0 0.0 2 4 2.91 Line corrosion. 74 2363 0 0.09 36 2 2.91 Line corrosion. 75 2395 0 0.08 31 4 2.91 Line corrosion. 76 2427 0 0.09 37 3 2.92 Line corrosion. t. De osits. 77 2458 0 0.09 35 2 2.92 Line corrosion. Sli ht Bucklin . 78 2490 0 0.09 35 4 2.91 Line corrosion. 79 2522 0 0.10 41 3 2.90 Line corrosion. 80 2554 0 0.08 31 :3 2.89 Line corrosion. Lt. De osits. 81 2585 0 0.09 35 4 2.90 Line corrosion. 82 2617 O 0.09 36 4 2.92 Line corrosion. 83 2648 (> 0.07 28 4 2.91 Line corrosion. Sli ht Bucklin . 84 2679 U 0.06 25 2 2.90 Line corrosion. 85 2711 O 0.10 40 6 2.91 Line corrosion. 86 2743 l1 0.09 35 2 2.92 Line corrosion. 87 2774 U 0.09 35 2 2.91 Line corrosion. 88 2806 U 0.12 46 2 2.91 Line corrosion. 89 2837 0 0.08 33 3 2.91 Line corrosion. 90 2870 0 0.07 28 4 2.91 Line corrosion. 91 2901 (1 0.10 40 5 2.94 Line corrosion. 92 2933 (1 0.10 39 5 2.92 Line corrosion. Sli ht Buckli~ . 93 2965 ll 0.11 44 6 2.91 Line corrosion. 94 2996 0 0.10 40 2 2.92 Line corrosion. 95 3026 (~ 0.10 40 6 2.91 Line co~rosion. 96 3057 l1 0.08 33 6 2.92 Line corrosion. 97 3089 0 0.09 37 4 2.91 Line corrosion. 98 3121 t) 0.09 36 6 2.92 Line corrosion. _. Penetrabon Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION S~Ef Pipe: 3.5 in 93 ppf L-80 EUE 8RD-MOD Well: 1 D-125A Body Wall: 0.254 in Field: West Ssk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 30, 2009 Joint No. Jt. Depth (FtJ f'E~n. U~xet (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Pro61e (%wall) 0 50 100 99 3152 c) 0.09 36 4 2.91 Line corrosion. 100 3183 (1 0.10 39 3 2.92 Line corrosion. Sli ht Bucklin . 101 3215 0 0.10 41 5 2.92 Line corrosion. 102 3245 0 0.09 35 3 2.91 Line corrosion. 103 3276 (~ 0.09 34 "; 2.93 Line corrosion. 104 3308 U 0.12 46 5 2.90 Line corrosion. 105 3339 l1 0.12 47 4 2.90 Line corrosion. 106 3371 0 0.11 42 4 2.91 Line corrosion. 107 3402 0 0.08 32 6 2.92 Line corrosion. Sli ht Bucklin . 108 3434 0 0.09 36 (i 2.91 Corrosion. 109 3464 0 0.09 36 4 2.94 Corrosion. 110 3496 O 0.11 43 7 2.91 Corrosion. 111 3527 0 0.10 39 5 2.90 Corrosion. 112 3559 0 0.11 44 6 2.90 Corrosion. Sli ht Bucklin . 113 3590 0 0.10 38 6 2.91 Corrosion. 114 3622 0 0.09 33 ~i 2.92 Corrosion. 115 3654 0.06 0.10 41 6 2.93 Corrosion. 116 3685 0 0.10 39 6 2.91 Corrosion. 117 3717 0 0.11 43 7 2.91 Corrosion. 118 3748 0 0.10 39 6 2.92 Corrosion. 119 3779 0 0.11 42 b 2.89 Corrosion. Sli ht Bucklin . 120 3811 0 0.11 42 6 2.91 Corrosion. 121 3842 0 0.10 39 6 2.91 Corrosion. 122 3874 0 0.10 38 7 2.90 Corrosion. 123 3906 0 0.10 39 6 2.88 Corrosion. 124 3938 0 0.09 35 6 2.91 Corrosion. 125 3969 0 0.09 34 6 2.90 Corrosion. 126 4001 t) 0.09 37 7 2.88 Corrosion. Sli ht Bucklin . 127 4031 0 0.09 37 6 2.88 Corrosion. 128 4063 ll 0.09 37 7 2.91 Corrosion. 129 4094 0 0.09 37 7 2.91 Corrosion. 130 4126 0 0.12 46 F3 2.91 Corrosion. 131 4157 0 0.10 41 6 2.91 Corrosion. 132 4189 0 0.09 35 6 2.91 Corrosion. 133 4220 l) 0.11 44 7 2.91 Corrosion. Sli ht Bucklin . 134 4252 0 0.10 40 9 2.90 Corrosion. 135 4282 0 0.12 46 6 2.93 Corrosion. 136 4314 (1 0.10 38 6 2.93 Corrosion. 137 4345 0 0.09 35 7 2.91 Corrosion. 138 4377 0 0.10 39 5 2.91 Corrosion. 138.1 4407 0 0.11 43 4 2.92 PUP Corrosion. Sli ht Bucklin . 138.2 4422 0 0 0 0 N A GLM 1 Latch ~ 11:30 1383 4428 0 0.09 36 3 2.95 PUP Corrosion. 139 4443 0 0.13 50 4 2.93 Corrosion. 139.1 4474 ll 0.11 42 2 2.89 PUP Corrosion. 139.2 4480 l) 0 0 ll 2.81 Camco DS-Ni le 1393 4482 O 0.07 26 3 2.89 PUP Corrosion. 140 4487 0 0.09 36 5 2.92 Corrosion. Sli ht Bucklin . 140.1 4519 ll 0.06 24 2 2.91 PUP Isolated~itting. 140.2 4525 O 0 0 0 2.98 Baker 45-40 S ecial Clearance PBR w 10' Seal Nenetration Body ~ Metal Loss Body Page 3 PDS• ORT OINT TABULATION S~ET 1 Pipe: 3.5 in 93 ppf L-80 EUE 8RD-MOD Well: 1 D-125A Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 30, 2009 )oint No. Jt. Depth (Ft.) P~n. UF~set (Ir~s.) Pen. Body (Ins.) Pen. % Metal Los~ % Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 1403 4539 0 0.09 35 4 2.92 PUP Corrosion. 140.4 4549 U 0 0 l) 2J9 Packer 141 4559 0 0.08 32 4 2.95 To of 3.5" Liner. Line corrosion. 142 4591 l) 0.10 39 3 2.96 Line corrosion. 143 4624 U 0.08 31 2 296 Line corrosion. _ Penetration Body Metal Loss Body Page 4 ~ ~ a^ ~ ~ ~ r ~^i^ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~c~ PDS Report Cross Sections 4 Well: 1D-125A Survey Date: June 30, 2009 Field: West Sak Tool Type: UW MfC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 f L-80 EUE 8RD-MOD Anal st: C. Waldro Cross Section for Joint 139 at depth 4473.21 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 % Tool deviation = 38 ° Finger 3 Penetradon = 0.127 ins Corrosion 0.13 ins = 50% Wall Penetration HIGH SIDE = UP Cross Sections page 1 u • ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ `c~ PDS Report Cross Sections 1 Well: 1D-125A 5urvey Date: June 30, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 93 f L-80 EUE 8RD-MOD Anai st: C. Waldro Cross Section for )oint 105 at depth 3355.69 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 78 ° Finger 6 Penetration = 0.12 ins Line corrosion 0.12 ins = 47% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 . ~OfIOCO~II~~I~JS KUP e1lAttributes xAn le&N~ 1 D-125A TD :,~ ,,, .... ~ . weawre nrwwi FlNd Name wep staus ~ 500292290401 WESTSAK INJECTING 64.90 - - ~ Itmsl 2,967.38 na eun 1~1 5,639.0 ... ---- ~ --- Commmt N15~ppm~ ~V: NONE 0 - --- _ ..-- Date Amaatlon EndDate 1!1/2009 Last WO: M712000 NB~Wtlpl) 47.50 ItlgReleaseDY &12/1998 wan a~. - t s i z9 a M ~c n~d-f -- Amotauon D~Ptl~ IRK6) B~d e Atnohqon L ast 6bU 6y B~d Date I a.n Tao: CTMD 5.569.0 6f212009 Rev Reason:TAG. 128' RATHOLE krwsbor 6/722009 16 15.062 47.5 121.0 121A 62.58 H-40 WELDED yM~- am0~-~ TW1~) EatDeplhlf_ SetDepM(TVDl._ SMngWt. SMn9-. SMi9TopMi 51/2 4.950 40.9 4.719.Q 3,213.0 15.50 L~0 BTCM fig O_ IStrIrW D_. op $N 6-iqF .. Sef ( _ SuLg .. ~ap' If n 31l2 2.992 4.529.7 5.636.5 4,D60.5 9.30 480 IBT-MOD coNDUCioR, __~ , t+ O(1 YH I81K <&121 TpP p~~ (Tw) Top ticl ToP I~I ~~~ (') Item oesv~pnm caoment GASLFf, aAO~ 2$.7 28.7 -1. HANGER VETCOTU&NGHANGER t . j 4,459.6 2,992J 35.33 NIPPLE CAMCO'DS' NDIN NIPPLE ~ ' ~ ~ 4,504.4 3,029.9 3378 LOCATOR BAKER LOCATOR NIP%.E.l,t60 4,505.8 3,031.0 33J5 PBR BAKER '45-40 SPECIAL CLEAR4NCE PBR w/10' SEN.S 4,529.4 3,050.4 33.22 SEAL ASSY M ~EL KBH-22' ANCHOR SEAL ASSEMBLY Other In Hole Ireline retrievable luc s valves, um s, fish, etc. LOCATOR. I.~ Top~ltlm) op oepm (ND) ~~) Top lrcl (°) DescNptlon Canmeft R~n 43 43. -1.30 PATCH 3' SUR ACE CSG PA CH down 3'11"kom slarter head ~~l'. Perto-atlons 8 3bts vea, e.soa Top~ND) Btm~TVq sh« Dens TW (~1 e~ IKKSI I~~1 M~1 Zone Date IsR" rype Canm«t sEai.assr. 5,096 5J30 3,663.9 3.595.3 WS D, iD-725A 5/JN2000 4.0 IPER 180 DEG PH, 2.5" HC [ i~aF. s,xias,zs~ ~F. 5,I52-5,260 IPERF, 5.770.5.186 IPFRF. 5.28&5.30t IPERF. IecnlTCD (~) I~) I 7 I MMe I MotlN I flM I 9en ~ 7Y0~ I T1Pe I M) I~Wsl) I IM Ds~ I Cati I IPERf, 5,3153,38! IPERf, 5.3965.410 LINER. ~.530.5.636 TD (16115A), S,H39 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 9, 2009 Mr. Tom Maunder .- bl;~'~~c '~' ,;' ; ~ r`; ~~` Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ JuN 1 r zoos ~9aska OiB Gas Cons. Comrnss~crr Anchora~a doa - o~c~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped May 27~', 2009. The corrosion inhibitor/sealant was pumped May 31St and June 1St, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,.`"j~%/ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor __ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 6/9/2009 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off -date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-06 ..181-116 n/a 0.25 22" 5/27/2009 1.70 5/31/2009 1 C-08 181-052 9'6" 3.50 20" 5/27/2009 1.30 5/31/2009 1C-15 198-229 4'10" 1.00 25" 5/27/2009 3.40 5/31/2009 1D-125A 200-044 4'9" 1.00 10" 5/27/2009 4.50 6/1/2009 1 H-03 182-115 15' 10" 2.00 24" 5/27/2009 2.60 5/31/2009 • Conoco~Phillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 1, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: u ~~r ~uN ~ 2 zoca~ :~~BSI(~ ~~S ear t7~$ ~f~R~r ~ ~t3173l~l~SiQ!'i ~~1CtlQCr3~E Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1D-125A PTD 200-044 surface casing excavation and repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, -~' MJ Lo~nd ConocoPhillips Well Integrity Projects Supervisor Enclosures • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .~` ~~~ 1. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ ' . ~~ ~ ~~~r~a~ / Sc Patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Ext/ ~ ~0/~1~8t5Slt3t Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 200-044 3. Address: Stratigraphic ^ Service^ ' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22904-01 7. KB Elevation (tt): 9. Well Name and Number: RKB 100' 1 D-125A 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5639' ' feet true vertical 4051' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' PRODUCTION 4619' S-1/2" 4719' 3212' LINER 1107' 3-1/2" 5636' 4060' Perforation depth: Measured depth: Perfs fr 5096'-5410' true vertical depth: 3564-3853' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4529' MD. Packers &SSSV (type & measured depth) packer Baler SABL 4530 no SSSV, no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/q Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N!A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: - Contact MJ Loveland/Pe Klein Printed Name ~ Title: Well Integrity Project Supervisor 7043 D Ph 659 te '~~~ Signature ~ one - a /~/2009 e ~ ~ ~ ~ i U Form 10-404 Revise 4 ~ IC11V ~ ~ ~~~~ d'u ~'i Submit Original ~~ • 1 D-125A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/28/Of Started nitrogen purge via IA and Conductor jewelry, had to use high side of manifold for the conductor. Civil cut and removed two 21" X 20" windows from conductor, as well as stand late and ussets. Cleaned surface casing for inspection .Found two holes within 4" of collar. Marked surface casing for inspection. T/I = 0/0. 05/01 /09 Prep for SC removal. Bleed T/IA to zero. Rig up purge manifold on IA. Purge IA with nitrogen @ 5% with oxygen down and no LEL's. Remove 5' 1" of conductor and chip cement out. Cleaned and ready for Kakivik to inspect. T/I = 0/0. 05/07/09 State Inspector John Crisp waived opportunity to witness damage. 05/21/09 05/22/09 05/23/09 05/25/09 Rigged up nitrogen purge, electricians installed cooper heat. Welded two wedding bands, "A" band begins @ starting head and is 20" long, "B" band is 16- ong an ens a ow starting head. Wedding bands are made from API-5L GR X65 pipe. Return in AM to install sleeve. T/I = 0/0. Rigged up nitrogen purge and dewatered cellar. Welders finished weld on "A" and "D" bands . Kakaavik MT/UT wedding bands " A" and "D" (Passed). Welded (incomplete) 3' sleeve of 6.625 O.D..432 wall pipe, return in A.M. to complete weld with fill and cap..Overall length of patch is 3' 11" from starting head down. Rigged down nitrogen purge. T/I = 0/0 Rigged up nitrogen purge and de watered cellar. Repaired wind damage to hooch. Completed weld on 6.625" OD, .432 wall sleeve. Called QC for mt/ut inspection of weld (Passed). Rigged down purge jewelry and re installed VR plug on opposing side of IA valve. Normal wellhead.jewelry re installed. Ready for MIT-IA.T/I =0/0. MIT- IA (Passed). Rigged up triplex to IA valve. Pre MIT T/I = 0/0. Pressured to 500 psi checked for leaks, no leaks observed. pressured to 1000 psi, no leaks observed. Pressured to 2000 psi, no leaks observed. Pressured to 2950 psi using 1.4 bbl of diesel. Int. T/I = 300/2950, 15 min T/I = 300/2900, 30 min T/I = 300/2850. Re pressured to 3000 psi. Int T!I = 300/3000, 15 min T/I =300/3000, 30 min T/I = 300/3000. Bled IA to 0 psi. Final T/I = 0/0. No fluids to surface observed. Called insulators to denso wrap surface casing. Ready for conductor installation. Welded 4'- 9.5" X 16" conductor pipe to existing conductor. Drilled one 4" hole for cement top- off. Ready for cement top-off.T/I =0/0. Summary Welded Production Casin patch from startin head down 3'11" , MITIA passed I w ~}~ rP • ~ ~ }~~~ ~~ ~: 4 ~. h + ,'rig } '~ • '~ f n..i ,'t .'- ,i . ~. ~,. d .T '~ ~ _ # r ~ . ~ - .~ r~.- ~ 9. ' ~ • ~ f ¥t F ~~ ~ . , ZC"' '~ ~~ ~ S 3 ,~ ~ it ','' i t ~` \ `,b ~ r ~ t`l ` 3 f I h1 -,., ,-. 7t a . ~ [. ~ ~ ^~ 3 Y ~.. ^i .. r ~ _ Y l 4 _ 1 ` "f^ ~`~ ... YZ __~ a _ ~J a. i ~.L~~ -~`~}~ r , " y-- ~, -~ i ,~ .., ;~~ 1 ~.~. ._ ~f ,r'" .... ,~ w , , ~ 4 ~. f ' .~ ~ ~ ~. :~P~. r~ v~ r~ ~ ~..,.r f ~ ~ Y' ~, . t ,~ ~! i '~' 1r R ~ t air.. i~ `~ pi ~ • ., ~~ r ,- t- ~ "n A.. ~. i ~" ~ ~ ~ ~ d .. ~' .r r, :~ :. .~_._ _ .. w -~.~. r i. . T i ~ I, ~~ • ALASSA OIL Ai~TD GAS C01~5I:RQATIOIQ COMi1'II55IOl~T • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisior ConocoPhillips Alaska Inc. ~, PO Box 100360 ~~~ '~~,'~~ ~~,_: °~L~ r- ~.~ ~~4, Anchorage AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, I D-125A Sundry Number: 309-054 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of February, 2009 Encl. \J U ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2009 --Et~ 1 7 lUiJ~ Alaska Oi1$ ~4 Cons ~omm+ssion Anchorage Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1D-125A PTD 200-044 surface casing excavation and repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~,. rr MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures (~^~~,, ~~ ECEI~lEC? r STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ FEB 1 ~ Z009 APPLICATION FOR SUNDRY APPROVII~ska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ SC repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 200-044 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22904-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO^ 1D-125A . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 ' RKB 100' Kuparuk River Field /West Sak Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5639' ~ 4051' Casing Length Size MD ND Burst Collapse CONDUCTOR 121' 16" 121' 121' PRODUCTION 4619' S-1/2" 4719' 3212' LINER 1107' 3-1/2" 5636' 4060' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Perfs fr 5096'-5410' 3564-3853' 3-1/2" L-80 4529' Packers and SSSV Type: Packers and SSSV MD (ft) packer Baler SABL 4530 no SSSV, no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service '^ " 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 1, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Perry Klein Printed Name MJ Loveland! Perry Klein Title: Well Integrity Project Supvr. Signature ~;'/ ," ~~,..,~ -~_,.,~' Phone 659-7043 Date `'"~ y ~' ~ ~ Commission Use Onl Sundry Number: ~~ Conditions of a roval: Notif Commission so that a re resentativ ma witness pp y p y e Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ J~- ~,~Fr ~ Other: Subsequent Form Required: 1.~-~i.,, w / ~\ _ S ~~~W~~~ ~,~ ~ ~C:~~ ~ ~C i ~- ~ ~ APPROVED BY ~~/ 1 Approved by: CO. ~ ,~ TN MMISSION Date: Form 10-403 Revised 0 O6~- ~ ( t ~. ~ "° ~ ' ~ ~ `_~ " ~ ._ ubmit in Duplicate • ConocoPhillips Alaska, Inc. Kuparuk We111D-125A (PTD 200-044) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02/14/09 This application for Sundry approval for Kuparuk well 1D-125A is for the repair of a surface ~ casing leak. The well is completed with a 5-1/2" x 3-1/2" tapered casing/liner and is a produced water injector, completed in May 2000. On September 27, 2008 the well failed an MITIA with fluid to surface. The AOGCC was notified of the problem the next day. The well was immediately plugged until diagnostics could be performed. Diagnostics located the leak in the surface casing approximately 1' below grade level. With approval, repair of the surface casing will require the following general steps: Shut-in and secure well. Set positive pressure plug and fluid pack as needed to remove all gas. PT the plug to verify barrier. DONE 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-IA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. NSK Problem Well Supervisor 08/01/05 Kuparuk Drill Site 1 D Well No. 125 casing leak Page 1 of 1 • • Maunder, Thomas E (DOA) From: Crisp, John H (DOA) ~ ~ ~ ~ ~~ Sent: Tuesday, September 30, 2008 8:22 AM To: Regg, James B (DOA) ~~~ - ~ ~~"~ Cc: Maunder, Thomas E (DOA); Grimaldi, Louis R (DOA); Noble, Robert C (DOA); Scheve, Charles M (DOA); Jones, Jeffery B (DOA) Subject: FW: Kuparuk Drill Site 1 D Well No. 125 casing leak Got this call from Jim Short last night. From: NSK Env Coord Donnelly&Short [mailto:n1037@conocophillips.com] Sent: Monday, September 29, 2008 8:55 PM To: Crisp, John H (DOA) Cc: Iversen, Allison K (DNR); DeRuyter, Thomas R (DEC); Wood, Graham M (DEC); Regg, James B (DOA) Subject: Kuparuk Drill Site 1D Well No. 125 casing leak John- Just to confirm our earlier conversation with regard to a 1 to 2 gallon diesel spill that occurred when pressure testing the casing on Drill Site 1 D, Well No. 125 at Kuparuk on September 27, 2008 at approximately 3:30 pm. After having noticed a pressure drop, a unit was brought in to pump up the pressure. The surface casing leak was discovered when 1 to 2 gallons of diesel was released in the cellar. The well has been secured for evaluation and repair. Please let us know if you require further information. Thanks. Jim Jim Short Kuparuk Environmental Coordinator 659-7242 <<,. 9/30/2008 1D-125A (PTD 2000440) Report of SC leak Fage 1 of 1 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, September 28, 2008 8:26 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1 D-125A (PTD 2000440) Report of SC leak Attachments: 1 D-125A schematic .pdf; 1 D-125 90 day TIO plot.jpg Tom, Jim West Sak water injector 1 D-125A (PTD 2000440) failed a MITIA with fluid to surface up the conductor on 09/27/08. The well was reported earlier in the day that the IA pressure dropped. The TIO was 1000/0. The immediate action action to shut the well in. A diagnostic MITIA was performed and failed. The well was added to the monthly failed MIT report. The well will be secured with a WRP in the tubing and diagnostics will continue to determine the depth of the leak. If the leak is shallow enough to excavate and repair, it is ConocoPhillips intention to submit the 10-403 for a sleeve repair. Attached is a 90 day TIO plot and a wellbore schematic. «1D-125A schematic .pdf» «1D-125 90 day TIO plot.jpg» Please let me know if you have any questions. Brent RogerslMartin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/30/2008 KRU 1D-125A PTD 200-044 9/28 2~~UCu TIO Pressures • • Y^ .a ~~~ Cot~ocoPf~riliips Alaska, inc. KRU 1 D-125A 1 D-125A API: 500292290401 Well T e: INJ An le TS: de TUBING _ SSSV T e: NONE Ori Com letion: 4!11 /2000 An le TD: 23 de 5639 (0-4529, ~ Annular Fluid: Last W/O: Rev Reason: TAG FILL OD:3.500, Reference Lo Ref Lo D ate: Last U date: 7/19/2006 ID:2.992) i, Last Ta : 5265 TD: 5639 ftKB Last Ta Date: 7/17/2006 Max Hole An le: 65 de 2967 ~I Casin $trln -ALL 'RODUCTION -) Descri lion Size To Bottom TVD Wt Grade Thread (o-471s OD:5 5o0 CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED . , Wt 15.00) r rj PRODUCTION 5.500 0 4719 3201 15.00 L-80 BTCM . , : ^ ' LINER 3.500 4529 5636 4049 9.30 L-80 EUE 8RD s Tubin Strin -ALL '.` ~ ~` Size To Bottom TVD Wt Grade ________Thread 3.500 0 4529 3039 9.30 L-80 EUE 8RD -- Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 5096 - 5130 3552 - 3584 WS D 34 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP 5160 - 5194 3611 - 3643 WS B 34 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP 5210 - 5234 3658 - 3680 WS A4 24 4 5/30/2000 IPERF 180 DEG PH, 2.5" HC DP NIP 5252 - 5260 3696 - 3704 WS A3 8 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP (x459-4460, OD:3 500) 5270 - 5288 3713 - 3729 WS A3 18 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP . 5298 - 5304 3738 - 3744 WS A3 6 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP 5324 - 5338 3762 - 3775 WS A2 14 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP 5350 - 5365 3786 - 3800 WS A2 15 4 5/30/2000 IPERF 180 DEG PH 2.5" HC DP 5375 - 5384 3809 - 3817 WS A2 9 4 5/29/2000 IPERF 180 DEG PH 2.5" HC DP 5396 - 5410 3828 - 3841 WS A2 14 4 5/29/2000 IPERF 180 DEG PH 2.5" HC DP Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 1 4400 2933 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 4/11/2000 Other lu s e ui .etc.. -.J EWELRY PBR (4505-4506 De th TVD T e Descri lion ID , OD:4.795) 4459 2981 NIP CAMCO DS NIPPLE 2.812 4505 3019 PBR BAKER 80-40 WITH 10' SEALS 2.985 4530 3039 PKR BAKER SABL-3 PACKER 2.780 LINER (4529-5636, t DN.39 O t 30) PKR ~ (4530-0531, OD:5.500) Perf _ _.._- (5096-5130) _-___..... _---- .----- -._.... Pert --.._...- - -- ~~ (5160-5194) ' _ - - ~, Perf (5210-5234) ------ --- -- ', I Pert ----_... -...- --- (5252-5260) I _ _-.... - Perf (5270-5288) I Perf ----- _._ I (52985304) ....._...._..- .._....- _... Pert (5324-5338) Perf (5350-5365) Perf ~- -- -- (5375-5384) Pert (5396-5410) . Conoc~illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: . RECEIVED JUL 1 0 Z007 Alaska Oil & Gas Cons. Commission Anchorage 5GA.~NfD JUL 11 2007 J,ÓO - 0 ttlf Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name pro # cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 619/2007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/9/2007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/9/2007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 619/2007 10-118 197-229 2" na 1 61912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/912007 10-127 198-109 8" na 2.5 619/2007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-51 02 RE : Cased Hole/Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowfedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~'C#\NNf:[:') 130 West Intemational Airport Road ~, . .' ~., Suite C Anchorage, AK 99518 Fax: (907) 245-8952 r '1 !' 2DDß '" ~t ,j 1) 2) 3) 4) 5) 6) 7) 1 Report 1 Report 1 0 - 1 06 10 - 122 MTT Log MTT Log MTT Log 13-0ec-06 l).IC- 14 '.-=1 --;;Hð 1 Report 10 - 125A 14-0ec-06 U:Ie.. I q 'ð - i.i../4 €4DeC.Q6 W:c. ::\óO"'1?~ f Print Name: ¡ ! ( 1/ JJ.A_--'· ' ~- 1\ (i f\ rì~~~ 'I () I) Vì r\J /1 ' ¡ ( (J . /I \",-",""'"~...', 7'1!' j,,,'_-~ '" " 'I~_, ~/. I_'j ,,.-....0:,1 . Da.te : ' Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAX: (907}245-8952 ... ,:"-.....~F.]!:;;:::,;:;~. :....: .~. ~:.., WEBSITE :.';'¡,'P:.::2::;L::;::' ,,'.::.:v:;::>: E-MAIL: - D,\OO _ PDSANC- 2006\Z, W ordlDístnbutionlTransmittal, Sheets\Transmit, Original, doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-125A Log Date: December 14, 2006 Field: Kuparuk Log No. : 7632 state: Alaska Run No.: 1 API No.: 50-029-22904-01 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intv!.: 194 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intv!.: 194 Ft. (MD) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intv!.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 194'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT too!. A maximum 7% isolated metal loss is recorded at 37'. A 5% isolated metal loss is recorded at 4'. A 3% isolated metal loss is recorded at -1' just below the mandrel hanger. A 3% circumferential metal loss is recorded in the interval between 4' - 31'. A 3% circumferential metal loss is recorded in the interval between 34' - 37'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5",5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. ~ r ..", "'""¡, Field Engineer: J. Halvorsen Analyst: M. Tahtouh & J. Burton Pro.,L\ctiv'E; Diagnostic Ser/)ces; Inc, Box Stafford" TX 7ì497 ,.... Phone: (281) or (888) 565-9085 Fax: 565·1369 E-mail: PDs@memOi-y!og.d~H¡~L Pr'udhoe Bay Field Office Phone: (907) 659-2307 Fax: (90ì) 659-2314 I\\ø~k.ª Qit & An~ihH~ijj;l 1 C ¡in1m¡¡;~ipn ,·"~W,,,·,_~; u....LC- 8Cö -Cfl-l I I I I I I I I I I I I I I I I I I I cI2 . )5. Magnetic Thickness Tool (10 HZ Pass) PROACTIvE DIAGNOSTic SERvlcE5, iI.c. Database File: d\warrior\data\1 d-125\1 d-125.db Dataset Pathname: 10HZ,1 Presentation Format: 2,6 scale Dataset Creation: Sun Dee 1709:19:392006 by Calc Sonc!ex Warrior V7.0 Charted by: Depth in Feet scaled 1150 _. -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 . -LU '. I -. I Tree Line S I I ¡ - Hanger -3% Metal Pup Jt I I Loss '5% M,etalt "~~- .- '- 3,5" Collar_ Loss I -I-- .,- I··..· i!t~ - ,,- ...- !-'.-- I n_ ""~ -- n__ 1-- f.- 1-.- -.. 3.5" --. -^~--·T~ Jt 1 , , 20 -.--.. ~ -- '-- ~3% Met~1 Loss I ·=¡=r+~ ,. e-- -. ,-- -., I 3.5" Collar- ,-c. "- __.m - ... 7% M I---- I .......,. Pup Jt L~SSI 1··- 4U I-- I I.T 1-... ..·,·,·5 ,5" Collar .5" Collar I- I-- ..-- I j--f-- I---- ~ !-....- 1----- .'- ,...- I-- I , ; ~ --- 3.5" - - Jt. 2 -- I ~~.- ._- 60 -- : -- =fA _._- --- .- ,- --. ~ f--- ~ .- f---- =- I-- ~ 1-..·--·· - .. ..- .,. '- -1 f'- - I I "'3.5" Collar I----- ~ ]I ! \1 ---1-----1__1--_. I./l V I.../p, ",.-,/ - Botto¡ of ~ 6" Conductor IV (' (P V ( I I 80 :(' { I I I-J ! 1\ !I¡;' - , '.. " ... - ,-.J c- -."... I I I I I I I I I I I I I I I I I I I ~> I I ~ ""-r~ !::~~~' cT~!. =9 1 '- '-. I-- --+-j ..__ _ _,_'._ _,_ ~__ _.1_,.., --- .-.-. - --- .. --~~' .., -. -- ". ¡:¡" '~ Collar -___ M___ -.. -, ~~5 :;" COllar~ --! '- ---. T 3.5" Collar 1 1 '-.- -'-'-- - --,., 1-.- .'1-- "- --"----.-.." "-. "-""-- _m~ 5.5" Col~~_1:t,lar i ~^- ~-'^ ,_ __n __ _ _ ___ ___ ___..__ ________ ( t , -!-.J _ , f---.- - +- i..... End ot' I "n I ."'f -50 Delta Metal Thickness (%) o Line Speed (ftlmin) ___ _______m..____ 50 -200 ::> :::;:::. 3.5" Jt 3 ~.L_ 100 -, - , [ -- I I 3.5" Jt 4 - ~ 120 -. ==- '- r~ ~, ---- -,- ~ - 140 - 3.5" Jt 5 160 180 35" Jt 6 --, . < -= - .-' ,.....!-.- 12.6 -5.2 -f-- ~ I I 'C -- t> >L ~.:::? ~ - -. 1---- \ é Î .1' [ - , .- -- .- . ~ t -- ~ I -.-' -.,- ---. -, _.,- - ç-~-- ~ ~ I·~ " -. ----,- > ~~t#~ --------- .-- ~~ . ---: '--. ---.- :c._ -~ "--- ,- - I-- 1 ~ 1: (:" 1(- -' :¡¡;-- ~ - ~ - ---- --- - ~ f--- w:-- ,.- ~.i- ¡.. r-- --- - _'_n_ ----, - -tl-- '-. --,--- - -'- MTTP01 (rad) MTTP12 (rad) - - -.- - =.- - ------- W' ~ ? . ' 12.6 3.8 I I I I I I I I I I I I I I I I I I I cI2s. Magnetic Thickness Tool (10 Pass) p~ DiAqNC>STic SERvlc"",, INC. Database File: d\warrior\data\1d-125 top 0'-12' metal loss\1d-125 db Dataset Pathname: 10HZ,1 Presentation Format: 2.6 scale Dataset Creation: Sun Dee 1709:19:392006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 125 -50 Delta Metal Thickness (%) 50 26 MTTP01 (rad) 12.6 0 Line Speed (ftlmín) -200 -6.2 MTTP12 (rad) 3.8 I \ I , 1 I I I - I \ I ;:;:;;> ~ I Tree ¡...... Line I I I 1~ I - Ha'!ger 3% Met~1 t I ~I, j:::-::; "'~. I I - Pup Jt. < ~ Loss I 'I"""'" '''., , -J- ~-, ¡.....:. I 3.5" Collar ¿ I ~. f) I I I ~ll; ) þ ~ Þ i~~ 1 J I ~O[}> 1<:-. -b<il} ) I I < I ,~ s~J (r ~~,,~þ ) >(~; /:;1 ( 5% MetaLJ2 H- < < ~':::. ) !-- , < '\ \ \ Loss I I I I I I > I ,< ( I I I 5 I < I ~ , I ? ~ II I \ ¡ ~ < ( I I ',) I I I \ 3.5" < :)~ ~ < Jt. 1 I cl I, ? I / ") ) , I I I Ii I I I) 10 ) 11 :: I I I '~ I I I? :: Il J ( I --"-_.._---~,..- -50 Delta Metal Thickness (%) 50 2,6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 l~f):~ MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I cI2 )'-~ Magnetic Thickness Tool (10 HZ Pass) p~ ÐÌAqNOSTlc SERvÎC.... INC. Database File: d\warrior\data\1d-125 4'- 31'\1d-125.db Dataset Pathname: 10HZ,1 Presentation Format: 2.6 scale Dataset Creation: Sun Dee 1709:19:392006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 160 -50 Delta Metal Thickness (%) 50 i2.i MTTPD1 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 I I I I Hanger 3% Metal Pup Jt I II Lo," ~r-r- -, .,- ~,---- r"- .... ..J 3.5" Collar ~ I~J , ). ~ --5% Metal 54 ... I I I I Loss I ¡. I I , I ê~ I I .~ ~' I I - I I 10 , -.Lne speedJ_ ) . ) I , - '- '-' . f-- I I "- ! 1 j I :> .- , I 3.5" I ! Jt 1 I I _r~ Ii,," . -, -=~ l' , jti ,j 20 I I ~ I I ) "; I I , I , I r-- 3% Metal Loss "\ '( I I ! , I ç::- ~ ') I .¡ I I .., ._, ~ I <: I 30 I ¿Þ, I I ; I ~~ < ' I'~ " ~ -:" '~ {"'J:' Ì3: ,I... '" tì l:. 1":~ #fF:-- [') '- ~ ¿ _L_~__ --~_.^--~._--~.- ~.JIL '- -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickness Tool (10HZ Pass) p~ DIAq",o.TÏc SEIt\IÌC"" INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted d\warrior\data\1d-125_3 30-4Q'\1d-125.db 10HZ,1 2.6 scale Sun Dee 1709:19:392006 by Calc Sondex Warrior VTO Depth in Feet scaled 125 Ii? I I 1 :¡ i, I ( ) i ?I ~ )1 < J, ,t ~ \ \/ ~ <: D '~ r\ì \'j r\~~ If It>~I{t'j ~ I ~~, " ==- -;:. j V I r <"" t {~¿þ lr7 I~ < l > > r~ ' tf {¡ '" ;::::; .)) < ( .> < 1 r:> {J::': " ~l, ~ <. <:: ) <~, "K Jl:::::.: ~ IY(, ~ :::' ;, ;i í~ ~~ <~ ( :f;~ I 5 j ~ 'j'j~:';r> \ ['$1,.3 ~> ~ l~ <ì> '~~ ~ \ ;~ ~ \ ~)~r:j If ç:~ ';;:::. -::f-~~'jj'þj 'þ~::::j (~;:I'j"'j) . "'? l~i~)) ! C:... <.;' <:::t;- c'2 r :;:;;: \: I 'i, ~ It (~j ( I J:::', I';::" < (1 I ,> L} I / I{ {Oo I ; '\. \. ¡'" \. ¿~ \, ';< (: ) ,J Ir~,:"'" )..:} I J) ) (rj~"""""",,¡;- '1 V /: <;:> ,}( I I < ;: J c 11~""j >- (, <: ( ~ ~ ,ç) ~ (,I( <)~ <if i : Þ jj~ ~ 2.6 MTTP01 (rad) -6.2 MTTP12 (rad) -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 2.6 -6.2 ) 30 3,5" ~ ( ,~ t 1\ "(" '< < ~f: í'-¿ I '¿ ¡'f., (, I 3.5" Collar~- - Jt. 1 ¡~..~ Line Speed I I I I I I I - ~% fV1et~¡ L~ss I I I I q - 7% Metal Loss ') I ,I--i-- ~il I''l, .5" Collar-- 40 3.5" Pup Jt - 55" CoJlar Q 3.5" / .' Jt 2 I ~_L -50 o Delta Metal Thickness (%) 50 Line Speed (ftlmin) -200 MTTP01 (rad) MTTP12 (rad) 12,6 3,8 12.6 3.8 I KRU 1 D-125A I l-1r11)1:1< API: 500292290401 Well Tvne: INJ An Ie IâJ TS: dea IâJ TUBING ...... SSSV Tvoo: NONE Orio Comaletion: 4/1112000 Anole d¡)'TD: 23 deo IâJ 5639 (0-4529, Annular Fluid: LastW/O: Rev Reason: TAG FILL 00:3.500, Reference Loo: Ref Loo Date: Last Uadate: 7/1912006 10:2,992) Last Tan: 5265 TD: 5639 ftK8 LastT an batA:' Max Hole An I...· 'RODUCTION Description Size Ton Bottom NO Wt Grade Thread (0-4719, 00:5,500, CONDUCTOR 16,000 0 121 121 62,58 H-40 WELDED Wt15,OO) PRODUCTION 5,500 0 4719 3201 15.00 L-80 BTCM LINER 3,500 4529 5636 4049 9,3( L-80 EUE 8RD . All Size I Ton I Bottom I NO r Wt I Grade I Thread Ã~()() I 0 4529 I 3039 I 9.30 L-8C I EUE 8RD Interval NO Zone Status Ft SPF Data TVDe Comment 5096·5130 3552 . 3584 WSD 34 4 5/3012000 IPERF 180 DEG PH, 2.5" HC DP 5160·5194 3611 . 3643 WS8 34 4 5/3012000 IPERF 180 DEG PH, 2.5" HC DP NIP 5210 - 5234 3658 - 3680 WSM 24 4 5/3012000 IPERF 180 DEG PH, 2.5" HC DP (4459-4460, 5252 - 5260 3696 - 3704 WSA3 8 4 5/3012000 ¡PERF 180 DEG PH, 2.5" HC DP 00:3,500) 5270 - 5288 3713 - 3729 WSA3 18 4 5130/2000 IPERF 180 DEG PH, 2,5" HC DP 5298 - 5304 3738 - 3744 WSA3 6 4 5/3012000 ¡PERF 180 DEG PH, 2.5" HC DP 5324 - 5338 3762 - 3775 WSA2 14 4 5/3012000 IPERF 180 OEG PH 2,5" HC DP 5350 5365 3786 - 3800 WSA2 15 4 5/3012000 ¡PERF 180 OEG PH, 2,5" HC OP 5375 - 5384 3809·3817 WSA2 9 4 5/29/2000 IPERF 180 DEG PH, 2.5" HC DP 5396 - 5410 3828 . 3841 WSA2 14 4 5/2912000 IPERF 180 OEG PH. 2,5" HC DP Gasil.ift 8t/ MO NO Man Mfr Man Type, V Mfr / V Type I V OD latch I Port I TRO Date I Vlv Run Cmnt 1 44~93:; CAMCO KRG>?SJ :AMr.O DMY 0 ¡NT I 0 000 T 0 PBR ili !!liri,"""'\IJ::\AlI:::IRV (4505-4506, Den1h TVDe Descrintion 10 OD:4,795) 4459 2981 NIP CAMCO OS NIPPLE 2.812 4505 3019 PBR BAKER 80-40 WITH 10' SEALS 2,985 4530 3039 PKR BAKER SABL-3 PACKER 2,780 LINER (4529·5636, OD:3,500. Wt9,30) PKR (4530-4531, 00'5,500) Perf (5096-5130) -- == - -- Perf - ~...... (5160-5194) -- - - Perf - f---- (5210-5234) -- 1----.- - 1--,.- - 1- Perf '- -- (5252-5260) -.- - - .- - ,- Perf - -- (5270-5288) --- -,- - - -- - Perf - -- (5298-5304) --- -- Perf - 1---- (5324-5338) -- 1----- Perf -- -,-- (5350-5365) - -- Perf - --- (5375-5384) - - Perf '- --- (5396-5410) -- f.---- I I I I I I I I I I I I I I I I I RECEIVED A.Uf; () 0 2006 08/01/06 Scblumbel'gel' NO. 3899 ~ Oit & Gas Cons. Comm~ Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth U:I c-- f)OO - Cy'lzl êöpy ';;;'C' ¡>. \\í\\\ED V .'(:;J"t:1\,,~, r' 1 ~ 2nD~ \'1 .l 1.':_ .., 0' , Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor n 'I ~~f1 7( 2sfC~ DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-125A K.UPARUK RIV U WSAK 1D-125A áêO-OLfLf FROM: JeffJones Petroleum Inspector S rc: Inspector Reviewed By: P.I. Suprv ~f2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK !D-12S!', API Well Number SO-029-22904-0 1-00 Inspector Name: Jeff Jones . Insp Num: mitlJ06071117S0S6 Permit Number: 200-044-0 Inspection Date: 7110/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 1D-125A iType Inj. i W i TVD 3039 I IA I 0 2020 1940 I 1930 I I I -L- i ! I ¡ I -----+-- : I ! P.T. 2000440 iTypeTest ! SPT i Test psi ! 1500 I OA i I I I I . ! ----1- I I i Interval 4YRTST P/F P / Tubing i 1200 I 1250 i 1200 I 1200 I i Notes Monobore injector, 0.9 bbls diesel pumped. 1 well house inspected; rlO exceptions noted. L L~ Wednesday, July 12,2006 Page 1 of 1 PRODUCTION (0-4719. 005.500, Wt15.00) NIP (4459-4460, 00:3.500) PBR ( 4505-4506, 004.795) e KRU 1 D-125A 500292290401 NONE I Well T e: IINJ Or! Com letion: 4/1112000 Last W/O: Ref La Date: TO' 5639 ftKB Max Hole An Ie 65 de 2967 5639 Bottom 121 4719 5636 TVD 121 3201 4049 Thread WELDED BTCM EUE 8RD Thread EUE 8RD Ft SPFI Date T e Comment 34 4 5/3012000 IPERF' 180 DEG PH, 2.5" HC DP 34 4 5/3012000 ¡PERF, 180 DEG PH, 2.5" HC DP 24 4 5/3012000 IPERF 180 DEG PH, 25" HC DP I 8 4 5/3012000 ¡PERF 180 DEG PH, 2.5" HC DP 18 4 5/3012000 ¡PERF 180 DEG PH, 2.5" HC DP 6 ' 4 5/3012000 IPERF 180 DEG PH, 2.5" HC DP I 14 4 5/3012000 ¡PERF 1180 DEG PH, 2.5" HC DP 15 4 5/3012000 ¡PERF 180 DEG PH, 2.5" HC DP 9 4 5/2912000 ¡PERF, 180 DEG PH, 2.5" HC DP 14 , 4 i 5/2912000 I ¡PERF ,180 DEG PH, 2.5" HC DP Port Vlv Cmnt 0000 : CAMCO DS NIPPLE BAKER 80-40 WITH 10' SEALS I BAKER SABL-3 PACKER lD 2.812 2.985 I 2.780 LINER (4529-5636, 00:3.500. Wt:930) Perf (5096-5130) Perf (5160-5194) Perf (5210-5234) Perf II (5252-5260) I! I !, i' Perf Ii , (5270-5288) 'I I, :i Ii Perf Ii (5298-5304) il Perf ii (5324-5338) Ii I, Perf ![ (5350-5365) II I' Perf II (5375-5384) '1 II Perf Ii (5396-5410) Sc~lIII~e.,. NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 éJw -ê.>4j Field: Kuparuk Well Job# Log Description Date BL Color CD cr 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1E-1()5L 1 11213766 INJECTION PROFILE 06/20/06 1 1 B-18 N/A PRODUCTION LOG WIDEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1 J-156 11216308 US IT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06105/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-13 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 . 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test " l\\"1 \0':;' \ \<etf\ Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska KRU 10 11/03/05 Arend/Sauvageau AES -' 0 ~L\- éJ.- 00 Packer Depth Pretest Initial 15 Min. 30 Min. We1l1D-125A Type Inj. S TVD 3,039' Tubing 1150 1150 1150 1150 Interval 0 P.T.D. 2000440 Type test P T est psi 1500 Casing 260 2500 2450 2430 P/F P Notes: Diagnostic MIT OA NA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) ~ÇANNEt) NOV 1 ? 2005 2005-1103_MIT_KRU_1D-125A.xls e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION / Mechanical Integrity Test \0 0 I/\t? /' '1 fz"c., v Email to:Tom_Maunder@admin.state.ak.us;BobFleckenstein@admin.state.ak.us; Jim Regg@admin.state.ak.us J~ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West SakI KRU/1D-125 07123/05 Arend I Rodgers - AES o F o P o P Well P.TD. Notes: Well P.TD. Notes: Well P.TD. Notes: Test Details: , ,<)\ r)DOÇ¡ ",\110.'.. ;:;':" V'.I(ì\; (1 ¡,¡; t.' . ~G!\~'G!,!p;;..t~) \~ . . TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0723_MIT _KRU_1 D-125A_MITIA.xls ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. '~ê4tf ¡jZI{u5 P.I. Supervisor N l t . DATE: Thursday, May 19,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHll.LIPS ALASKA INC lD-125A KUPARUK RIV U WSAK lD-125A d~Ú;;CJtFt} FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed B~f:- P.I. Suprv . Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-125 API Well Number: 50-029-22904-01-00 ^ Insp Num: mitJJ050518081201 Permit Number: 200-044-0 Rei Insp Num: Inspector Name: Jeff Jones Inspection Date: 5/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lD-125A Type Inj. w TVD 3039 IA 0 1650 1610 1600 P.T. 2000440 TypeTest SPT Test psi 759.75 OA Interval 4YRTST P/F P Tubing 1000 1000 1000 1000 Notes: "Monobore" type injector. 1 well house inspected; no exceptions noted. ~Cio\~\tNED ;~UG 0 ~g 2005 Thursday, May 19,2005 Page 1 of 1 ) .PHILLlPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY TUBING 11Ð425Ä (0-4529, OD:3.500, 10:2.992) PROOUCTION (0-4719, 00:5.500, Wt:15.00) NIP (4459-4460, 00:3.500) PBR (4505-4506, 00:4.795) LINER (4529-5636, 00:3.500, Wt:9.30) ·\@I',·,""lli,.: t r ~i "~~ Perf (5096-5130) Perf (5160-5194) Perf (5210-5234) Perf ( 5252-5260) ...-.----..-. Perf ( 5270-5288) Perf (5298-5304) Perf (5324-5338) Perf (5350-5365) Perf (5375-5384) Perf (5396-5410) API. 500292290401 SSSV Type' NONE Annular Fluid. Reierence Log: Last Tag: 154ìO Last Tag Date' 7/20/2001 Casing String - ALL Description CONDUCTOR I· PRODUCTION liNER I Tubing String - ALL I ,~~~~ I, T~P ¡PerfOrations Summary , ~I~~~e_~~~o I j55~~~.Ö.1 I -:; 160 . ';) 1 '~J . :St· 1 1 . 3':' J) ! ~·211.1. ~ 2 .:SJ J~.~. '3 . j6öÜ I 5252· ::'213(1 :16~6 . 3 ;"(IJ , -:'27(1. ~,';'13~ j71j. 'F29 ! S29d . 5~~i)J );' jlj - 3 ìJ.1 ~'j2.1 - 533:3 j;'':'2 . 37~5 :.jSü - -:'3135 37f. 6 . 3:300 ~ F'J . ')j13J 3~Ü'3 . :~81;- 5H6 - W 10 )lj21j - 3.:3.11 ,Gas Lift MandrelsNalves 1St MD TVD Man! Man Mfr I Type ,1 4400 2933 CAMCO KBG29 CAMCO Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 4459 2981 NIP 4505 3019 PBR 4530 3039 PKR ) KRU 1 D-125A I Well Type: INJ OrlQ Completion: ~/11l2000 Last W/O: Ref Log Date: TD: 5639 ttKB Max Hale Angle: 65 deg @ 2967 Angle ,~ TS:! deg @ Angle @ TO: 123 deg @ 5639 Rev Reason: I Tag by ImO Last Update: i 8/2/2001 I Size 16.000 5.500 3.500 TVD Wt Grade Thread 121 62.58 H-40 WELDED 3201 15.00 L-80 BTCM 4049 9.30 L-80 EUE 8RD Wt Grade Thread 9.30 L-80 EUE8RD Top o o 4529 Bottom 121 4719 5636 Bottom 4529 TVD 3039 Zone W~D WS8 VV:. ...J I/VS ':') I/IJ ~ ':'j IIvS ":\ ~'V 3 :¡;:: I/V :; :¡.:: ~'J 'S .:.¡ I I/V:'';''¿ I Status I ! I I I I j-1 jJ ¡.1 :3 13 .; 1.1 1~ ~ lJ J 5..jÜo'':Oljlj J 5 30,' 21)1)ù J ~.. )It'¿Ù(IL) J I &;,·'{"II-d"I(II'"1 .1 i ;.11),2Õ¿Û J I -:;, :'O¡¿( (II) .1 5, jl);';"OOú .1 50'31),'20I)lt .1 'S. :':::'~,'2( Ij(, J 5, .:'90'20(11) Ft SPF Type ¡PERF IPERF IPERF IPERF IPERF IPERF ¡PE.RF' ¡PERF IPERF IPERI= Comment i~O DEG PH 2'5 Ht: DP 1~1j [lEG PH 25 He: DP 18(' DEG PH .2 -:, HC DP 103(' DEe. PH .2 ') Ht: OP 181) DEG PH 25 I- !': DP 1~1) DEG PH :2 -:, Ht: OF' 11~() DE":::' PH ;¿ 5 H(: DP 18Ct DEG PH ¿ 5 HC DP 1~ù DEG PH ;:,~. HC DP t~(1 DEG PH ¿ 5 Hf: DP Date V Mfr V Type V OD II Latch 'I Port TRO Date Run DMY 1.0 INT i 0.000 0 4/11/2000 Vlv Cmnt Description ID 2.812 2.985 2.780 CAMCO DS NIPPLE BAKER 80-40 WITH 10' SEALS BAKER SABL-3 PACKER MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill No. 2000440 MD 5639 TVD DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. KUPARUK RIV U WSAK 1D-125A Operator PHILLIPS ALASKA INC. 4051 Completion Date 5/29/2000 -----~'"~ Completion Status lWINJ Current Status APl No. 50-029-22904-01-00 REQUIRED INFORMATION Mud Log No Samples No Directional Survey .. -No~' -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Log Log Run Interval OH / Scale Media No Start Stop CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments Injection Profil ~'/LIS Verification 5 FINAL 4900 5450 OH C 25 FINAL 4689 5639 CH 25 FINAL 4689 5639 CH FINAL 54 5639 OH 8/3/2001 2/22/2001 09912 2/22/2001 2/22/2001 2/23/2001 4/24/2000 BL~Sepia /~683-5604 BL, Sepia BL, Sepia LIS Verification Paper Copy SPERRY 4672.. Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Receive~ Analysis Received? Daily History Received? (~)/N Formation Tops Receuived? "~ / N Comments: Compliance Reviewed By: SchlUmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1338 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 7/31/2001 Well Job # Log Description Date BL Sepia CD Color '~ -~Y"{~ 1D-125A INJECTION PROFILE 07120101 1 1 1 D-132 INJECTION PROFILE 07/20/01 1 1 2C-12 PRODUCTION PROFILE 07/23/01 1 1 2W-11 PRODUCTION PROFILE 07124101 1 1 1D-130 INJECTION PROFILE 07/19/01 1 1 1 C-123 21345 CBL/USIT 07/11/01 1 1 C-127 21346 CBL/USIT 07113/01 1 DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. RECEIVED 2001 WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-125A, AK-MW-00016 February 08, 2001 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-125A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22904-01 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-029-22904-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-125A, AK~MW-00016 February 08, 2001 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-125A: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22904-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22904-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation CoMW. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs February 01,2001 AK-MW-00016 1 LDWG formatted Disc with verification listing. AP1//: 50-029-22904-01 PLEASE ACKNOWLEDGE RECElPT BY SIGNING TRANSMITTAL LETTER TO THE ArlTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 AND RETURNING A COPY OF THE Date: Signed'~~t~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIw~$SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil F~ Gas BI Suspended F~ Abandoned m'] Service [~ ...... Water injector i 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ~ 200-44 3. Address~ f 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22904-01 4. Location of well at surface r .... "m'~.~. ~:':-~' 9. Unit or Lease Name 286' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM (ASP:560491,5959379) i Kuparuk River Unit At Top Producing Interval ~ .~'%?_'¢.~,.,,...~-o 10. Well Number 1539' FNL, 1838' FWL, Sec. 23, T11N, Rt0E, UM (ASP:557659, 5958106) ~ -,.¥- ,: ,. i:.i-~ ~ 1D-125A 1575' F~[., 1625' FWL, Sec. 23, '1'11 ~, [:t10~, UM (ASP: 557446, 5958065) ~ ....................... Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 28.7' feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 7, 2000 April 9, 2000 A~ 5'. 2.?/- ¢~',.,5'~Ii N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 5639' MD / 4051' TVD 5538' MD / 3959' TVD YES r~ No r-1I N/A feet MD 1960' (approx) 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 272 sx AS II 5.5"x 15.5# L-80 Surface 4719' 8.5" 593 bbls AS III & 94 bbls Class G 3.5" 9.3# L-80 4529' 5636' 4.75" 41 sx AS II 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5396'-5410' MD 3828'-3841' TVD 4 spf 5324'-5338' MD & 3.5" 4530' 4530' 5375'-5384' MD 3809'-3817' TVD 4 spf 3762'-3775' TVD 4 spf 5096'-5130' MD 3552'-3584' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5160'-5194' MD 3611'-3643' TVD 4 spf 5350'-5365' MD & DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5210'-5234' MD 3658'-3680' TVD 4 spf 3786'-3800' TVD 4 spf 5252'-5260' MD 3696'-3704' TVD 4 spf 5270'-5288' MD 3713'-3729' TVD 4 spf 5298'-5304' MD 3738'- 3744' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Water Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29~ NAME Top West Sak D Base West Sak D West Sak Base GEOLOGIC MARKERS MEAS. DEPTH 5090' 5134' 5549' TRUE VERT. DEPTH 3547' 3587' 3969' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Chip Alvord Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection_, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental reCords for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. :,- ~. ~,' ,~'~.: ...... :'' Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 05/24/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lD-125A STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:04/05/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22904-01 04/05/00 (D1) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 5779/0 (5779) PULL 3.5" TBG HANGER TO FLOOR CAME FREE ~ 100K LOOK'S SUPV:DONALD L. WESTER Turn key rig move well to well from 1D-110A to 1D-125A. Accept rig ~ 0900 hrs. 4/5/00. Rig up. PJSM. Circulate out diesel. Pump down tubing with sea water. Set BPV. N/D tree. Test BOPE 300/3000 psi. 04/06/00 (D2) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 4719/3175 ( 0) M/U WHIPSTOCK ASSY & RIH SUPV:DONALD L. WESTER Continue circulating seawater. POOH. Pull tubing. RIH with mill, casing scraper, junk basket. POOH with mill. PJSM. RIH with bridge plug to 4708' POOH. 04/07/00 (D3) MW: 9.2 VISC: 62 PV/YP: 14/36 APIWL: 6.5 TD/TVD: 4719/3200 ( 0) CONTINUE RIH W/ 4.75" DRILLING BHA. ORIENT ~ WINDOW 46 SUPV:DONALD L. WESTER RIH with 5.5" Baker window master whipstock assy. Top whipstock 4689'. Shear off whipstock. Displace sea water w/9.1 ppg m~%ing fluid. Mill out 5.5" casing. Start cutting out ~44689 came off face of whipstock @ 4702' drilled t~oa4719'. Ream through window till clean. Circulate and condition mud for FIT, EMW = 10.6 ppg. POOH. PJSM. RIH with BHA #4 on 2-7/8" DP. 04/08/00 (D4) MW: 9.3 VISC: 55 PV/YP: 15/25 APIWL: 4.5 TD/TVD: 5639/4051 920) POOH L/D MWD, R/U TO RUN 3-1/2" LINER ~ 0600 HRS M/U 5 SUPV:DONALD L. WESTER Slide out from 4719' to 4822'. Rotate and drill 4.75" hole to TD ~ 5639' Circulate hole clean. Short trip to 5.5" window ~ 4689' Wash and ream to bottom @ 5639'. Hole clean no fill. Circulate out light gas cut mud. Increase mud weight to 9.3 ppg. Monitor well. POOH to 5.5" window ~ 4689' Pump dry job. Continue to POOH. 04/09/00 (D5) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 5639/4051 ( 0) CONTINUE TO L/D 2-7/8" & DC'S. L/D 15 STANDS OF 3.5" D SUPV:DONALD L. WESTER PJSMo Run 3.5" special clearance collars casing Baker float equipment and Baker liner hanger. Wash 30' to bottom ~ 5639' PJSM. Pump cement. Bump plug. Floats held OK. Test Date: 05/24/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/10/00 (D6) TD/TVD: 5639/4051 ( SUPV:M.C. HEIM MW: 8.5 VISC: 0 PV/YP: 0/ 0 0) MOVING RIG TO 3H PAD APIWL: 0.0 POH lay down HWDP and DC,s. Change out handling equipment. Break down and lay down 3.5" DP in mouse hole. Run completion assembly. Tag. N/D BOPE. PJSM. N/U tree, test tree and packoff 250/5000 psi. Freeze protect well. Back rig off well. Rig released ~ 00:00 4/11/00. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-125(W4-6)) WELL 1 D-125 JOB SCOPE DRILLING SUPPORT-EXP WORKOVER JOB NUMBER 0320001904.3 DATE DALLY WORK UNIT NUMBER 04/19/00 GAS LIFT 70175 DAY OPERATION COMPLETE I SUCCESSFUL 4 YES I YES In'tialTbgPress IFinalTbgPress IlnitiallnnerAnn 50PSI 50PSI 0PSI DAILY SUMMARY SUPERVISOR CHANEY KEY PERSON HFS-CLEVELAND Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI REPLACED 1" DCK-3 SHEAR VALVE W/DV @ 4400' RKB, PT 7" TO 500#[GLV, PT Tbg-Csg] TIME LOG ENTRY 06:30 MI HES-TGSM-WORKING BY NORDIC-TS 1.875" ROLLER STEM RS,QC,5',KJ,5',KJ,LSS,QC 07:40 HOT OIL ON LOCATION 08:00 APC ON LOCATION 08:40 PULL BPV W/APC LUB, RIG DOWN APC EQ. 09:00 RU HES& HOT OIL, PT TO 2500# 09:15 RIH W/3" OK-1 & 1.25" JDC TO 4384' WLM (4400' RKB) PT TBG TO 1000# POOH W/DCK SHEAR VALVE ON BOTTOM LATCH, DCK SHEARED 10:15 HOT SHOT TO Y-PAD FOR BOTTOM LATCH DV 11:15 RIH W/3" OK-1 & 1" DV, ON BTM LATCH TO 4384' WLM (4400' RKB) SET, POOH RIG UP HOT OIL ON, 7" PT TO 500# HELD, BROUGHT BACK TO O# 13:10 RDMO PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-125A(W4-6)) WELL JOB SCOPE JOB NUMBER " 1D-125A DRILLING SUPPORT-CAPITAL 0424001537.3 DATE DAILY WORK UNIT NUMBER 05/29/00 SCMT/PERF 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 YESI YES SWS-ELMORE KENNEDY FIELD AFC# CC# Signed ESTIMATE AK0064 25WS1 D6DO Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 50 PSI 50 PSI 0 PSI 0 PSII 0 PSI 0 PSI DAILY SUMMARY RUN SCMT 5530'-4375' W/0 PSI AND 1500 PSI - CEMENT OK - DETECTED MICROANNULUS - PERF'D BOTTOM TWO A2 ZONES 5396'-5410' AND 5375'-5384' W/2.5" HC DP/4 SPF/180 DEG PHASING.[Perf] TIME LOG ENTRY 15:30 MIRU SWS 2128 ELMORE, TGSM, PT 3000#. 17:00 RIH W/SCMT. 17:35 CHECK UP WEIGHT AND TIE IN TO MWD GR AT 5100', CONTINUE RIH TO TD. 17:50 LU MAIN AND REPEAT PASSES 5530'-4375', @ 1800 FPH. 19:22 LU 1500# PRESSURE PASS AT 1800 FPH. 20:00 POOH. 20:35 AT SURFACE. RD SCMT, RU GUN 1. 21:40 PT LUB, RIH W/GUN 1, 14', 2.5", 31J UJ RDX, 4 SPF, 180 PHASED, ORIENTED +/- FLSH. 22:17 TI AT 4500', RIH TO TD. 22:30 LU JEWELRY LOG FROM TD - 4350' 23:00 LU TO SHOOT GUN 1 5396'-5410'. POOH. 23:27 AT SURFACE, RU GUN 2. 23:50 RIH W/GUN 2. 00:10 CK UP WT / TIE IN TO MARKER JTS AT 5000'. RIH. 00:02 LU TO SHOOT GUN 2 AT 5375'-5384'. POOH. 01:00 AT SURFACE, RD FOR THE NIGHT. LEAVE EQUIP SPOTTED ON WELL. 01:45 RDMO. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-125A(W4-6)) WELL JOB SCOPE JOB ~UMBER " 1D-125A DRILLING SUPPORT-CAPITAL 0424001537.3 DATE DAILY WORK UNIT NUMBER 05/30/00 PERFORATE 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 YESI YES SWS-ELMORE KENNEDY FIELD AFC# CC# Signed ESTIMATE AK0064 25WSl D6DO Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 50 PSI 50 PSI 0 PSI 0 PSII 0 PSI 0 PSI DAILY SUMMARY PERF'D: 5096-5130', 5160'-5194', 5210'-5234', 5252-5260', 5270'-5288', 5298-5304', 5324-5338', 5350-5365', LOGGED STATIC BHP I @ 5404' (MID LOWEST A2 PERFS)[Perf] I TIME LOG ENTRY 09:30 MIRU SWS 2128 ELMORE TGSM, REBUILD NEW WK POINT, PT3000#. 11:00 RIH W/SWIVEL, CCL-WTBAR, GUN #3, 15'. 11:30 TI TO SliT JTS. RIH TO 5420' 11:40 LU TO SHOOT 5350'-5365'. POOH. 12:20 RIH W/GUN #4. 12:47 TI TO SliT JTS 12:42 LU TO SHOOT GUN 4 AT 5324'-5338'. POOH. 13:11 RIH W/GUN #5. 6'. 13:30 TI TO SliT JTS 13:35 LU TO SHOOT 5298'-5304'. POOH. 14:03 RIH W/GUN 6.18'. 14:24 TI TO SHT JTS. 14:28 LU TO SHOOT 5270'-5288'. POOH. 15:00 RIH W/GUN 7. 8'. 15:25 TI TO SliT JTS. 15:30 LU AND SHOOT 5252'-5260'. POOH. 16:05 RIH W/GUN 8, 24'. 16:30 TI TO SliT JTS 16:35 LU TO SHOOT 5210'-5234'. POOH. 17:00 RIH W/GUN 9. 20' 17:35 TI TO SliT JTS. 17:40 LU TO SHOOT 5174'-5194'. POOH. 18:10 RIH W/GUN 10. 14'. 18:40 TI TO SliT JTS. 18:45 LU AND SHOOT GUN 10 AT 5160-5174'. POOH. 19:20 RIH W/GUN #110 19:50 TI TO SliT JTS. TIME 19:59 21:30 21:53 22:14. 22:26 23:00 23:59 LOG ENTRY LU TO SHOOT 5110'-5130'. POOH. AT SURFACE W/GUN 12, LAST GUN RUN, RD GUN, RU PL STRING FOR STATIC BHP. RIH W/2 WTBS, PRESS, TEMP, GR, CCL. TIE IN AT SHT JTS. LOG 20 MIN STATIC PRESSURE/TEMP @ 5404' (MID LOWEST A2 PERFS). POOH. AT SURFACE, BD LUB, RD. 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A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 14,2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-125A (200 / 044) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the sidetrack operations on 1D- 125A. If you have any questions regarding this matter, please contact me at 265-6120 or Brian Noel at 265- 6979. Sincerely, G. C. Alvord Drilling Engineering Supervisor PA1 Drilling GCA/skad 14-Apr-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-125A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,672.54' MD 4,689.00' MD 5,639.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) ;,Pr 24 2000 Gas Cons. Commission TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHON[: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1D-125A ARCO' Alaska, Inc. Permit No: 200-44 Sur. Loc. 286'FNL, 599'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. 1575'FNL, 1640'FWL, Sec. 23, TllN, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours)of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH..E (~OMMISSION DATED this 2.~ ~ day of March, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section u'/o encl. Department of Environmental Conservation xv/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work: Drill '~1 Redrill r-1 I lb. Type of well. Exploratory F1 ......... ~i'mtigraphicTesiD" De'vel;~ment°ilFl ........ Re-entry D Deepen D Service [] Development Gas D Single Zone [] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 Kuparuk River Pool .. 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.0251) 286' FNL, 599' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1559' FNL, 1829' FWL, Sec. 23, T11N, R10E, UM 1D-125A #U-630610 At total depth 9. Approximate spud date Amount 1575' FNL, 1640' FWL, Sec. 23, T11N, R10E, UM March 28, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1640 @ TD feetI 1D-126 1066' @ 4750' MD feet 2560 5650' MD/4055' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 4700 MD Maximum hole angle 30 o Maximum surface 1136 psig At total depth (TVD) 1527 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casing Wei~lht Grade Coupling Length MD TVD MD TVD (include stage data) 4.75" 3.5" 9.3# L-80 BTC-MOD 1086' 4550' 3058' 5636' 4055' 23 bbls Class G 'sidetrack - to_..~ 9f,wigd_,o~_G 4702' 19. To be completed for RedrilI, Re-entry, and Deepen Operations. __ Present well condition summary Total Depth: measured 5795 feet Plugs (measured) MAR 2 'l 2000 true vertical 4201 feet Effective Depth: measured 5685 feet Junk (measured) ~aS~.fi~.0il & Gas Cons. C0mmissl n Anchorage true vertical 4097 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 272 sx AS II 121' 121' Surface 4968' 5.5"x 593 bbls AS III & 94 bbls Class G 5009' 3465' Intermediate 5738' 3.5" 5779' 4186' Production Liner Perforation depth: measured 5445'-5450', 5090'-5095' true vertical 3872'-3876', 3540'-3545' ORIGINAL 20. Attachments Filing fee [~] Property Plat ~II BOP Sketch D Diverter Sketch D Drilling program D Drilling fluid program ~ Time vs depth plot DRefraotion analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Brian Noel 265-697~ Signed ~¢~ I~, ~,~ Title: Drilling EngineeringSupervisor Date '~l~.-~l~ Chip Alvord Prp. n~r~d bv ,~h~rnn AIl.~u~-F)r~k~ Commission Use Onl) Permit Number APl number I Approval date-~ ISee cover letter 2.4~O ,-- ~,/~v,,~' 50- O2-.~;~--.' ,~--,~--.-~:~:3 ~./-- o / --~)- ~j"' ~)Ifor other requirements Conditions of approval Samples required r-'J Yes ,,~ No Mud logrequired r"l Yes ~ No Hydrogen sulfidemeasures D Yes ~J~ No Directional surveyrequired ~ Yes D No Required working pressure for BOPE D2M; j~ SM; D 5M; D 10M;I--J J--J Other: ORIGINAL SIGNED BY by order of "-) ..., .--~ .~ __ Approved by .~.obert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate REDRILL PLAN SUMMARY Well 1 D-125 A Type of well (producer/injector): Surface Location: Target I - Top of D: TD: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Drill Fluids Proqram: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Injector 286' FNL, 599' FEL, Section 23, T11 N, R10E, UM 1559' FNL, 1829' FWL, Section 23, T11 N, R10E, UM 1575' FNL, 1640' FWL, Section 23, T11 N, R10E, UM 5,636' 4,055' Nordic Rig 3 3/28/0O 9 Drilling Fluid 9.1 8-14 15-25 45-55 4-7 8-11 <10 9.0-9.5 4-8 Drillinq Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Casin_clrrubin~ Proclram: Hole size Cs~/'l'bcl Liner 4-3/4" 3-1/2", 9.3#, L-80, BTC Mod- Special Clear. Tubing 3-1/2", 9.3#, L-80, EUE 8rd Mod Length Top (MD/TVD) Btm (MD/TVD) 1086' 4,550' / 3,058' 5,636' / 4,055' 4,550' Surface 4,550' / 3,058' Cement Calculations: West Sak Abandonment: Casing to be cemented: D sand squeeze perfs at 5,090' - 5,095' (6spf) Volume = 10 bbls, Class G Based on: 1/4 bbl/perf and 2 bbls to fill 3-1/2" casing 3-1/2" in 4-3/4" open hole Volume = 21 bbls, 11.7 ppg ArctiCRETE Based on: Open hole volume + 60%, 150' liner lap, and 200' of cement above liner top. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 1136 psi and is calculated using a gas column to surface with a maximum expected formation pressure in the West Sak of 1520 psi (3550' tvd) and a gas gradient of 0.11 psi/ft. MASP = (3550 ft)*(0.43 - 0.11 psi/ft) = 1136 psi Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. See attached BOPE schematic. Drillinq Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: Sidetrack window is in upper Ugnu formation (Ugnu C). There is potential of lost circulation in the Ugnu and West Sak sands. Solids control and dilution will be used to maintain mud weight at 9.1 ppg (provides 150 psi overbalance). Lost circulation material will be onsite. No over/under pressured horizons anticipated. None. Directional: KOP: Max hole angle: Close approaches: 4,700' MD / 3,184' TVD (Nordic 3 RKB) 30° (in sidetrack portion at KOP) 65° (in original portion) Closest well is 1 D-126 with center to center distance of 1,066' at 4,750' MD. Lo(~c~inq Proc~ram: Open Hole Logs: Cased Hole Logs: GR GR/CCL/CBL Notes: All drill solids generated from the 1 D-125A sidetrack will be hauled to the designated Prudhoe Bay cuttings facility for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted Kuparuk disposal well. KRU 1D-125 A GENERAL PROCEDURE Pre-Ri.q Work: . RU slickline unit. RIH, drift 3-1/2" tubing to 'DS' nipple at 4958' RKB to verify that EZSV can be set. Attempt to establish injection into the upper squeeze perfs at 5090-5095' MD. Pressure test 5-1/2" casing to 3500 psi for 30 min. Note: If tubing restriction prevents running EZSV deep enough or injection rates too Iow, discuss CT P&A options with town engineer before proceeding. RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. Tie-in CTU depth with RKB depth and flag coil. Run and set EZSV at +/- 4955' MD (middle of 6' pup joint) just above 'DS' nipple. Squeeze at least 10 bbls of 15.8 ppg Class G cement below retainer. (2 bbl for the 3-1/2" volume below the retainer down to top of fish at 5155' MD + minimum 8 bbls into perfs.) If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and thoroughly circulate any excess cement from well (dummy valve will need to be pulled from the mandrel at 4900' RKB). Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. RU slickline unit. Bleed annulus pressure to 0 psi. Pressure test tubing above EZSV to 2500 psi for 30 min. Slowly bleed tubing pressure to 0 psi and monitor casing pressure for build-up. (Test to verify isolation of the perfs). 4. RIH and pull 1" DV from mandrel at 4900' RKB, leaving an open pocket. . RU E-line and cut 3-1/2" tubing at +/-4935' RKB (middle of full joint tubing below mandrel). Set BPV in tubing and install VR plug in annulus valve. Prepare location for Nordic 3. General Sidetrack and Completion Procedure: 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 9.1 ppg LSND mud and displace well. Shut in and monitor pressures to ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. Screw in landing joint..Pull tubing hanger to floor and POOH standing back 3-1/2" tubing. PU 2-7/8" DP, RIH and set bridge plug at +/-4720' MD, pressure test casing to 3500 psi, POOH. PU Baker 5-1/2" Window Master Bottom Trip Whipstock and MWD, RIH. Orient and set whipstock w/MWD. Shear off whipstock bolt and mill window in 5-1/2" casing and 20' formation. Perform FIT test to 10.0 ppg (max expected ECD at the window for 9.1 ppg LSND mud), POOH and LD milling assembly. RIH w/4-3/4" bit, MWD / LWD and steerable drilling assembly. Slide out window and directionally drill per plan through the West Sak sands to TD at +/- 5636' MD. POOH and lay down drilling assembly. . . . . 8. RIH with 3-1/2" liner to TD (150' overlap above top of window). Cement liner in place, set liner top packer, circulate out excess cement and POOH laying down 2-7/8" DP. 9. Pressure test casing and liner lap to 3500 psi for 30 min (Chart Test for State). 10. RIH w/3-1/2" completion assembly and sting into PBR of liner top packer. Space out. Displace well to sea water and land tubing. Test tubing and annulus to 3000 psi. 11. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic 3. Lower Limit: 5.5 days Expected Case: 9 days Upper Limit: 14.5 days No problems. Difficulties cutting window, drilling sidetrack. BDN 3/15/00 WEST SAK 1D-125 injector ARCO Alaska, lnc, Proposed Abandonment 16" ConductoJ@ 80' TAM Port Collar @ 1034' Depths are Parker 245 RKB 5-1/2r' 15,5# L*80 BTCM @ 5OO9' 8RD-Mod @ 5779' APl#: 50-029-22904 Original RKB: 111' Directional KOP = 500' Max Angle = 64.90 Deg @ 2979' Avg Angle Thru W.Sak = 20 Deg 5-1/2" Baker 'Window Master Whipstock' run on bottom trip anchor, 5-1/2" Baker Bridge Plug set on drill pipe @ +/-4720' MD. EZSV set at +/-4955' (Middle 6' pup joint above D nipple at 4958' Squeeze Perfs 5090' - 5095' (Above West Sak D sand) Post squeeze, milled cement to 5185' CTM, S~uck m0t0d!t~i!l, sheared off, unable to recover fish (top @ 5155' CTM) EZSV set at 5427' Squeeze Perfs 54,L5' - 5450' (West Sak A'~ ime~¥8 PBTD @ 5685' MD BDN 3/14/00 WEST SAK 1 D-125 injector Proposed Completion TAM Pod Collar @ 1034' Depths are Parker 245 RKB ARCO Alaska, Inc. APl#: 50-029-22904-0I RKB: t11' G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2", 9.3# L~80 EUE 8rd Mod tubing to surface E. 3-I/2" x 1" Camco 'KBG-2-9' mandrel w/DCR dump kill valve (3000 psi casing to tubing shear), 6' L-80 handling pups. D. 1 jt 3-1/2", 9.3# L-80 EUE 8rd Mod tubing. C, 3-1/2" Camco 'DS' nipple with 2,813" ID No-Go profile w~th 6' L-80 handling pups B. 1 jt 3-1/2", 9.3# L-80 EUB 8rd Mod tubing. A. Baker '45-40' special clearance PBR w/10' of effective stroke. 4.80" O.D. seal bore 4.0" I.D., seals 3,0" I.D. Model 'KBH' anchor seal assembly made up on bottom (2.78" kD.) and 6' L-80 handling pup installed on top of PBR. Top of Whipstock at +/-4702' MD Top of BP et +/-4730' MD Liner Equipment: 3-1/2" x 5-1/2" Baker'SABL-3' permanent packer run as liner top p~cker. Minimum tD through packer 2~780", 3-1/2" Liner, Landing collar/Float collar, 2 joints casing, Shoe, 5~1/2" 15.5# L-80 BTCM @ 5009' Squeeze Peds 5090'- 5095' FuturethroughtubingWest Sak D, B, A sand peds 8RD-Mod @ 5779' EZSV set at 5427' 5445' - 5450' PBTD @ 5685'MD 3-1/2" 9.3# L-80 BTC~Mod Soecia Clearance @ +/-5636' MD BDN 3/~4/00 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-125A WPs 3150 ] DrillQuest Proposal Data for 1D-125A Wp1 vertical origin:1D-125A Horizontal Origin: 1D-125A Measurement Units: ft North Reference:True North Dogleg severity: Degrees per lOOft Vertical Section Azimuth: 247.060° Vertical Section Description: 1 D- 125A Vertical Section Origin: O00 N,0.O0 E Measured Incl. Azlm. Vertical Northlnga Eaetlnga VerticalDogleg Depth Depth Section Rate 4700.0029.083243.854 3183.74 1246.98 S 2703.57 W 2975.78 4740.0030.015251.747 3218.55 1254.40 S 2721.8(I W2995.47 4852.0720.366265.404 3319.93 1264.78 S 2768.01 W 3(g12.(X'~ 10.(XX) 5091.0820.366265.404 3544.(X} 1271.44 S 2850.92 W 3121.01 5422.8220.366265.404 3855.00 t280.69 S 2965.99 W 3230.60 O.(XX) 5636.1520.366265.404 4055.00 1286.64 S 3040.(X) W3301.07 0.000 Current Well Properties Well: 1D-125A WPs Horizontal Coordinates: Ref. Global Coordinates: Ref. Well: Ref. Geographical Coordinates: RK8 Elevation: 5959379.35 N, 560490.59 E 524.87 S, 2.22 E 70° 17' 58.5094" N, 149° 30' 36.3613" W 95.0Oft above Mean Sea Level 95.0Oft above Well North Reference; Units: True North Feet out @ 10.000°/100ft, 80.000° TF: 4700.00ft MD, 3183.74ft TVD 3300 Dir: 4852.07ft MD, 3319.93ft TVD 345O ~ 3600 .-- 1D-125 Target 3544.00 TVD 1271.44 S, 2850.92 W West Sak D - 3544.00 TVD West Sak B - 3603.00 TVD West Sak A4 - 3636.00 TVD 'West Sak A3 - 3688.00 TVD 3750 ........................................................ West Sak A2 - 3757.00 TVD 39O0 .............................................. Base l.x)west Pay - 3855.00 TVD .c_ 4050 I-- I 3000 Scale: linch = 150ft I I 3150 3300 Vertical Section Depth: 5636.15ft MD, 4055.00ft TVD I 3450 Section Azimuth: 247.060° (True North) ] DrillQuest North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1 D-125A WPs Proposal Data for 1D-125A Wp1 Vertical Origin:1 D-125A Horizontal Origin: 1D-125A Measurement Units: ft North Reference:True North Dogleg severity: Degrees per lOOft Vertical Section Azimuth: 247.060° Vertical Section Description: 1D-125A Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azlm. Vertical Northlnge Eaatlnge VerticalDogleg Depth Depth Section Rate 4700.0029.083243.854 3183.74 1246.98 S 2703.57 W 2975.78 4740.0030.015251.747 3218.55 1254.40 S 2721.80 W 2995.4710.IX)0 4852.0720.366265.404 3319.93 1264.78 S 2768.01 W 3042.0610.(XX) 5091.0820.366265.404 3544.00 1271.44 S 2850.92 W 3121.019. tXX) 5422.8220.366265.404 3855.00 1280.69 $ 2965.99 W 3230.60 0.000 5636.1520.366265.404 4055.00 1286.64 $ 3(Ng.(x) W3301.07 0.000 Current Well Properllos Well: 1D-125A WPe Horizontal Coordinates: Ref. Global Coordinates: 5959379.35 N, 560490.59 E Ref. Well: 524.87 S, 2.22 E Ref. Geographical Coordinates: 70" 17' 58.5094" N, 149° 30' 36.3613" W RKB Elevation: 95.00ft above Mean Sea Level 95.00ft above Well Nodh Reference: True North Units: Feet -1200 -- c~rill out @ 10.( Total Depth · 5636. ~'ft_~D, 4055.0( OLO Z"" II c -1350 - .-- -- o Scale: linch = 150ft Eastings -3000 -2850 -2700 I I I I TVEndD Dir: 4852.(~r'7ft MD, 3319.93ftTVD~ \ ~ ....... I I I I -3000 -2850 -2700 Scale: linch: 150ft Reference is True North Eastings - 1200 -1350 ._ 0 Single Well Target Data for 1 D-125A WPs Measurement Units: ft Coordinate Target Point TVD TVD Northings Eastings Northings Eastings Target Name Type ss Shape 1D-125 Target Entry Point 3449.003544.00 1271.44 S 2850.92 W 5958085.00 N 557650.00 E Circle Proposal Data 3a55 405b, 00( 0.00000 .00000 - 1 - DrillQuest go'go'~ lsanOIl!JO - ~ - 8t~: ~ ~ - O00Z 'qoJe~ 8 '"penu!iuoo '(enJ.L) o090'zffg jo uoiloeJ!C] eq~ u! "~/_0' L0gg s! ~ueweoeldS!Q elOH wo~o~ '-~,cj L'989§ ~o q~deQ peJnseelA! e ~e 'suo!~elnOleO adX~ e~n~eAJno wnLu!u!IAi uodn pase~] '(em.L) o090'lffg jo q~nw!zv ue I~uole pelelnOleO pue ¥cjg~-Q L woJj s! uo!~oas leO!peA '~00 L Jed s@eJbeO u! s! X1!Ja^aS 6albOQ QA.L g00'gg0'¢ 'QIAI ~g L'9g9g: qlaea lelOJ. 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Llads Sperry-Sun Drilling Services Proposal Report for 1D-125A WPs - 1D-125A Wp1 Revised: 8 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 4700.00 4852.07 5636.15 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3183.74 1246.98 S 2703.57W 3319.93 1264.78 S 2768.01W 4055.00 1286.64 S 3040.0ow Comment Drill out @ 10.000°/100ft, 80.000° TF · 4700.00ft MD, 3183.74ft TVD End Dir · 4852.07ft MD, 3319.93ft TVD Total Depth · 5636.15ft MD, 4055.00ft TVD Formation Tops Measured Ve~ical Sub-Sea Depth Depth Depth Nothings Eastings Formation Name (~) (~) (~) (~) (~) 5091.08 3544.00 3449.00 1271.44 S 2850.92W West Sak D 5154.01 3603.00 3508.00 1273.20 S 2872.75W West Sak B 5189.22 3636.00 3541.00 1274.18 S 2884.96W West Sak A4 5244.68 3688.00 3593.00 1275.73 S 2904.20W West Sak A3 5318.28 3757.00 3662.00 1277.78 S 2929.73W West Sak A2 5422.82 3855.00 3760.00 1280.69 S 2965.99 W Base Lowest Pay Continued... 8 March, 2000.11:48 - 2 - DriilQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-125A WPs - 1D-125A Wp1 Revised: 8 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Targets associated with this wellpath Target Name 1D-125 Target Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3544.00 1271.44 S 2850.92 W 3449.00 5958085.00 N 557650.00 E 70° 17' 45.9983" N 149° 31' 59.4662" W Target Target Shape Type Circle 8 March, 2000- 11:48 -3- DrillQuest 1.05.05 7-1/16" 5u00 psi BOP Stack-- Nordic Rig 3 Kuparuk River Unit Operations I Kill Line 5 4 3 Choke Line 12. 13. Accumulator Caoacitv Test 1, Check and fill accumulator reservoir to proper level with hydraulic fluid. 2, Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3, Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4, Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4...Do not pressure test any choke that is not a full closing positive seal choke. Open top-pipe rams and-close-bottom-pipe rams. Test bottom-rams . to 250 psi and 3000 psi for 3 minutes. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. Test standpiPe v~l~e~-~-~O~30 p$1'f~r:'$-'minutes. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Pedorm BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one ':l" r, rlrtrt nc; i-Iyrlr=, ,I;~, n=~_t..=_ ,~nrt nn,', _':(" ;~rtn n~i M~n~ ,,~1 nat,, ~) Kill v~lv~ ..... I- ................... ~ .... r ........... ~---, ............' ..... are 3" 5000 psi gate 5. 7.1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB. 10/01/98, v.2 · 66/~60S-0~ ~a8~nN 6:L:~ L660 000~ "6 HOHV:~~ 688 WELL PERMIT CHECKLIST FIELD & POOL /--/?~ ~,~ ADMINISTRATION D~TE/ ENGINEERING APPR DATE COMPANY./~-~ WELL NAM~/',~-' PROGRAM: exp ~ INIT CLASS 1. Permit fee attached. ¢ 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... dev redrll serv ~ wellbore seg ~ ann. disposal para req ~ REA Y N Y N--- -- Y N Y N--- N N (~)N Y N N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If d/verier required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~O~C:) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y® GEOLOGY 30. 31. 32. 34. Permit can be issued w/o hydrogen sulfide measures ..... Y N ,,,,/' Data presented on potential overpressure zones ....... Y ,bi-"'" ,~.~ Seismic analysis of shallow gas zones ............. /~Y I~ Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [exploratory,~i'nly] ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving~ .... ~ APPR DATE (B) will not contaminate freshwater; o~ dr'riling waste... ~Y N to surface; ~ / (C) will not impa'~he well us~ed-ffir disposal; Y N (D) will ~ng formation or im, gai~ecovery from a Y N poo' d ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N UNIT# ,//,/~"~,,'"2 ON/OFFSHORE GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: TEIV~ / .~' Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX, No 'special 'effort has been made to chronologically organize this category of information. ,o ( c2 (j ~ - (1'1~ Memory Multi-Finger Caliper Log Results Summary ii' Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe1 Use: CONOCOPHILLlPS ALASKA, INC. July 30,2005 6514 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 D-125A Kuparuk Alaska 50-029-22904-01 Suñace 4,570 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 4,459' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the majority of the interval of 3.5" tubing logged is in good to fair condition, with a maximum recorded penetration of 48% @ 2,343'. Wall penetrations ranging from 20% to 48% wall thickness are recorded in 114 of the 151 joints logged. The damage recorded appears in the forms of Line Corrosion, Line of Pitting and some general corrosion. There are no areas of significant Cross Sectional Wall loss throughout the interval logged. Deposits restrict the ID to 2.70" @ 1,805'. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is iIIustr~ted in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line Corrosion Line Corrosion Line Corrosion Corrosion Line Corrosion ( 48%) ( 47%) ( 45%) ( 44%) ( 44%) Jt. Jt. Jt. Jt. Jt. 74 @ 138.1 @ 104 @ 120 @ 87 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: MAXIMUM RECORDED ID RESTRICTIONS: No areas of significant cross-sectional wall loss (> 13%) are recorded. Deposits Deposits Deposits Deposits Deposits Min ID= 2.70" Min ID= 2.70" Min ID= 2.70" Min ID= 2.70" Min ID= 2.72" Jt. Jt. Jt. Jt. Jt. 57 @ 78 @ 56 @ 101 @ 77 @ :--'''.".^·i~\t\.ii\.ìL~'\} /'\ ~JG ~:~ 1 ÎO(P~ ï\)"..¡I',jl'~ '(~~~I{;;~~~ t-H . I"~ ..., '_ ,.d I Field Engineer: N. Kesseru Analyst: J. Thompson 2,343 Ft. (MD) 4,400 Ft. (MD) 3,287 Ft. (MD) 3,802 Ft. (MD) 2,783 Ft. (MD) 1 ,805 Ft. (MD) 2,499 Ft. (MD) 1,774 Ft. (MD) 3,193 Ft. (MD) 2,437 Ft. (MD) Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds. Well: Field: Company: Country: lD-125A Kuparuk CONOCOPHILLlPS ALASKA, INC USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 EUE-8rd Penetration and Metal Loss (% wall) _ penetration body 150 IiœmJ metal loss body 100 --L. 50 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 151) pene. 0 1 36 103 11 loss 0 149 2 0 0 o o Damage Configuration ( body) 100 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 150) 11 58 81 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins July 31, 2005 MFC 24 No 99628 1.69 24 J. Thompson Nom. Upset Upper len. 3.5 ins 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) ~ metal loss body 50 _ penetration body o 0¡æ:- ! ''- 100 f . t 1- 49~ ~ 99r I GLM 1 141 ~, Bottom of Survey = 142 Analysis Overview page 2 ii, ìl PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 1 D-125A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC NominaIID.: 2.992 in Country: USA Survey Date: July 31, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (IllS.) (I ns. ) 01<) (Ins.) 0 50 100 .1 24 0 0.03 13 " 2.85 PUP Shallow pitting. .) 1 26 0 0.03 13 2 2.85 Shallow pitting. 1.1 58 0 0.05 19 ~) 2.85 PUP Shallow corrosion. 2 64 0 0.04 15 .1 2.85 Shallow pitting. 3 95 0 0.04 14 3 2.84 Shallow pitting. Lt. Deposits. 4 127 0 0.04 14 2 2.87 Shallow corrosion. Lt. Deposits. 5 158 0 0.03 13 2 2.85 Shallow pitting. Lt. Deposits. 6 190 0 0.05 20 4 2.86 Shallow C;Qrro~ion. 7 222 0 0.04 14 2 2.86 Shallow corrosion. Lt. Deposits. 8 254 0 0.04 17 2 2.83 Shallow corrosion. 9 285 0 0.04 15 2 2.87 Shallow corrosion. 10 317 0 0.03 13 2 2.87 Shallow pitting. Lt. Deposits. 11 349 0 0.04 14 3 2.84 Shallow corrosion. 12 380 0 0.04 15 .1 2.86 Shallow corrosion. 13 412 0 0.03 13 2 2.85 Shallow pitting. 14 444 0 0.04 14 2 2.85 Shallow pitting. Lt. Deposits. 15 475 0 0.04 15 2 2.86 Shallow corrosion. 16 507 0 0.04 14 2 2.86 Shallow pitting. 17 539 0 0.04 17 3 2.87 Shallow pitting. 18 570 0 0.04 15 3 2.88 Shallow corrosion. 19 602 () 0.04 14 3 2.84 Shallow corrosion. Lt. Deposits. ._:fQ .ÞJ.J. ... ...... n.. _...Q,Q4._ ..J~.. ..:L... __.~,ª5._ ......~h.ª!l.mX.._çºI!Q~QJ1,_.JJ..J2.~.P9Ji.i~~ --- .--_._--_._-~_._--- 21 665 0 0.06 22 :3 2.84 Corrosion. Lt. Deposits. 22 697 0 0.04 17 3 2.87 Shallow corrosion. 23 728 0 0.04 17 2 2.87 Shallow corrosion. 24 760 0 0.04 15 2 2.85 Shallow corrosion. Lt. Deposits. 25 792 0 0.04 16 2 2.86 Shallow pitting. Lt. Deposits. 26 823 0 0.07 26 3 2.86 Line of Pitting. 27 855 0 0.07 28 3 2.86 Line of Pitting. 28 886 0 0.07 28 3 2.86 Line of Pitting. Lt. Deposits. 29 918 0 0.08 32 5 2.85 Line of Pitting. Lt. Deposits. 30 950 0 0.09 34 3 2.86 Line of Pitting. 31 982 0 0.08 33 4 2.86 Line of Pitting. Lt. Deposits. 32 1013 0 0.07 30 4 2.86 Line of Pitting. 33 1045 0 0.07 27 4 2.84 Line of Pitting. 34 1077 0 0.07 28 3 2.84 Line of Pitting. 35 1108 0 0.06 24 2 2.85 Line of Pittin~. 36 1140 0 0.06 24 3 2.86 Line of Pitting. 37 1172 () 0.06 24 3 2.84 Line of Pitting. 38 1203 0 0.06 23 5 2.85 Line of Pitting. 39 1235 0 0.06 ' 23 5 2.86 Line of Pitting. Lt. Deposits. 40 1267 () 0.05 21 ') 2.83 Line of Pitting. Lt. Deposits. _J 41 1298 0 0.07 27 3 2.83 Line of Pitting. Lt. Deposits. 42 1330 0 0.04 18 2 2.82 Shallow Line of Pitting.. Lt. Deposits. 43 1361 0 0.04 16 2 2.73 Shallow Line of Pitting.. Lt. Deposits. 44 1393 0 0.07 28 2 2.77 Line of Pitting. Lt. Deposits. 45 1425 0 0.06 22 2 2.81 Line of Pitting. Lt. Deposits. 46 1456 0 0.07 28 3 2.81 Line of Pitting. Lt. Deposits. 47 1488 0 0.05 20 3 2.80 Line of Pitting. Lt. Deposits. 48 1520 () 0.05 20 3 2.78 Shallow corrosion. Lt. Deposits. I Penetration Body Metal Loss Body Page 1 ,( { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 1 D-125A Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC NominaII.D.: 2.992 in Country: USA Survey Date: July 31,2005 Joint Jt. Depth PCIl. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ills. ) (Ins.) (~{) (Ins.) 0 50 100 49 1551 () 0.04 16 2 2.78 Shallow corrosion. Lt. Deposits. 50 1583 0 0.04 17 4 2.81 Shallow corrosion. 51 1615 () 0.04 15 6 2.84 Shallow corrosion. Lt. Deposits. 52 1646 0 0.04 16 6 2.83 Shallow corrosion. Lt. Deposits. 53 1678 0 0.05 19 2 2.80 Shallow corrosion. Lt. Deposits. 54 1710 () 0.04 17 2 2.82 Shallow corrosion. Lt. Deposits. 55 1741 0 0.08 31 3 2.73 Line of Pitting. 56 1773 () 0.06 25 5 2.70 Line of Pitting. Lt. Deposits. 57 1805 0 0.06 22 7 2.70 Line of Pitting. Lt. Deposits. 58 1836 0 0.07 27 6 2.80 Line of Pitting. Lt. Deposits. 59 1868 0 0.07 29 5 2.77 Line of Pitting. Lt. Deposits. 60 1900 0 0.07 27 4 2.74 Line of Pitting. 61 1931 0 0.07 28 7 2.78 Line of Pitting. Lt. Deposits. 62 1962 0 0.09 34 4 2.78 Line of Pitting. Lt. Deposits. 63 1994 0 0.07 29 6 2.78 Line of Pitting. Lt. Deposits. 64 2025 0 0.06 23 5 2.79 Line of Pitting. Lt. Deposits. 65 2057 0 0.07 28 5 2.78 Line of Pitting. 66 2088 0 0.08 31 7 2.79 Line of Pitting. 67 2120 0 0.07 30 4 2.73 Line of Pitting. Lt. Deposits. 68 2151 . 0 0.08 31 4 2.73 Line of Pitting. Lt. Deposits. 69 2183 0 0.10 40 6 2.78 Line of Pitting. Lt. Deposits. 70 2215 0 0.08 32 7 2.78 Line Corrosion. Lt. Deposits. 71 2246 0 0.07 29 5 2.79 Line Corrosion. Lt. Deposits. 72 2278 O.OS 0.08 31 4 2.77 Line Corrosion. Lt. Deposits. 73 2310 0 0.08 31 3 2.78 Line Corrosion. Lt. Deposits. 74 2341 0 0.12 48 5 2.78 Line Corrosion. 75 2373 0 0.08 30 6 2.75 Line Corrosion. Lt. Deposits. 76 2404 0 0.08 30 6 2.70 Line Corrosion. Lt. Deposits. 77 2436 C) 0.07 28 6 2.71 Line Corrosion. Lt. Deposits. 78 2468 0 0.09 36 4 2.78 Line Corrosion. 79 2500 0.06 0.08 30 7 2.78 Line Corrosion. 80 2532 0 0.08 31 9 2.72 Line corrosion. Lt. Deposits. 81 2563 () 0.08 31 6 2.74 Line Corrosion. Lt. Deposits. 82 2595 0 0.09 35 7 2.74 Line Corrosion. Lt. Deposits. 83 2626 0 0.08 31 3 2.78 Line Corrosion. Lt. Deposits. 84 2657 0 0.09 34 3 2.78 Line Corrosion. Lt. Deposits. 85 2689 0.06 0.07 26 6 2.78 Line Corrosion. 86 2721 D.08 0.08 30 3 2.83 Line Corrosion. 87 2752 0 0.11 44 3 2.78 Line Corrosion. Lt. Deposits. 88 2784 0 0.10 39 8 2.80 Line Corrosion. Lt. Deposits. 89 2816 0 0.09 37 5 2.75 Line Corrosion. Lt. Deposits. 90 2847 0 0.07 28 7 2.76 Line Corrosion. Lt. Deposits. 91 2879 0 0.09 34 6 2.76 Line corrosion. Lt. Deposits. 92 2911 0 0.10 38 9 2.78 Line Corrosion. 93 2942 0 0.09 35 7 2.75 Line Corrosion. 94 2974 0.10 0.09 35 6 2.76 Line Corrosion. 95 3004 0 0.09 35 6 2.73 Line Corrosion. Lt. Deposits. 96 3035 0 0.08 31 5 2.77 Line Corrosion. 97 3067 0 0.11 42 7 2.77 Line Corrosion. Lt. Deposits. 98 3099 0 0.10 39 6 2.82 Line Corrosion. Lt. Deposits. I Penetration Body Metal Loss Body Page 2 ~, .~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 1 D-125A Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: CONOCOPH ILLlPS ALASKA, INC NominaII.D.: 2.992 in Country: USA Survey Date: July 31,2005 Joint Jt. Depth I)en. Pen. Pen. MC'tal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (I ns.) (Yo (Ins.) 0 50 100 99 3130 0.05 0.07 29 6 2.77 Line Corrosion. 100 3161 0 0.09 37 () 2.78 Line Corrosion. Lt. Deposits. 101 3193 0.07 0.10 39 7 2.70 Line Corrosion. Lt. Deposits. 102 3223 (LOS 0.07 29 7 2.74 Line Corrosion. Lt. Deposits. 103 3254 0.07 0.09 37 6 2.81 Line Corrosion. Lt. Deposits. 104 3286 0 0.12 45 6 2.75 Line Corrosion. Lt. Deposits. 105 3317 0 0.11 43 7 2.76 Line Corrosion. Lt. Deposits. 106 3349 0 0.10 39 6 2.73 Line CorrQ~iQn. Lt. Deposits. 107 3380 0 0.09 35 10 2.74 Line Corrosion. 108 3412 0 0.09 35 11 2.78 Line Corrosion. Lt. Deposits. 109 3442 0.'10 0.09 33 6 2.80 Line corrosion. Lt. Deposits. 110 3474 0 0.08 33 <) 2.80 Line corrosion. Lt. Deposits. 111 3505 0.09 0.10 37 9 2.78 Corrosion. Lt. Deposits. 112 3537 0 0.09 37 6 2.80 Corrosion. Lt. Deposits. 113 3569 0 0.10 39 7 2.79 Corrosion. Lt. Deposits. 114 3600 O.OB 0.09 36 6 2.80 Corrosion. Lt. Deposits. 115 3632 0 0.09 37 6 2.77 Line corrosion. Lt. Deposits. 116 3663 0 0.10 39 <) 2.81 Corrosion. Lt. Deposits. 117 3695 0 0.11 43 6 2.82 Corrosion. Lt. Deposits. 118 3727 0.07 0.09 35 5 2.78 Corrosion. Lt. Deposits. 119 3758 0.05 0.09 34 <) 2.77 Line corrosion. Lt. Deposits. 120 3789 0.05 0.11 44 <) 2.81 Corrosion. Lt. Deposits. 121 3821 0 0.10 38 7 2.81 Corrosion. Lt. Deposits. 122 3853 0.07 0.10 38 7 2.78 Corrosion. Lt. Deposits. 123 3884 0.06 0.09 36 B 2.77 Corrosion. Lt. Deposits. 124 3916 0 0.09 34 13 2.80 Line corrosion. Lt. Deposits. 125 3947 0 0.09 34 7 2.78 Corrosion. Lt. Deposits. 126 3979 0 0.09 35 a 2.75 Corrosion. Lt. Deposits. 127 4010 0 0.09 34 6 2.78 Corrosion. Lt. Deposits. 128 4041 0 0.09 36 6 2.82 Corrosion. Lt. Deposits. 129 4073 0 0.09 37 7 2.80 Corrosion. Lt. Deposits. 130 4104 0 0.11 43 8 2.83 Corrosion. 131 4136 0 0.10 38 6 2.80 Corrosion. Lt. Deposits. 132 4167 0 0.09 34 9 2.81 Corrosion. Lt. Deposits. 133 4199 0 0.10 39 7 2.83 Corrosion. Lt. Deposits. 134 4231 0.08 0.09 36 6 2.83 Corrosion. Lt. Deposits. 135 4261 0.06 0.09 35 <) 2.84 Co rrosion. 136 4293 0 0.08 32 B 2.86 Corrosion. Lt. Deposits. 137 4324 0 0.10 38 6 2.84 Corrosion. Lt. Deposits. 138 4356 0 0.10 41 9 2.84 Corrosion. 138.1 4386 0 0.12 47 7 2.83 PUP Corrosion. 138.2 4401 0 0 0 0 N/A GLM 1 (Latch @ 11 :00) 138.3 4407 0 0.11 43 6 2.85 PUP Corrosion. 139 4422 0.07 0.10 40 9 2.83 Corrosion. Lt. Deposits. 139.1 4453 0 0.10 40 4 2.77 PUP Corrosion. 139.2 4459 0 0 0 0 2.81 OS NIPPLE 139.3 4460 0 0.09 37 4 2.82 PUP Corrosion. 140 4466 0.09 0.09 37 <) 2.84 Line corrosion. Lt. Deposits. 140.1 4498 0 0.08 31 2 2.84 PUP Corrosion. Lt. Deposits. 140.2 4504 0 0 0 0 2.98 PBR ! Penetration Body ~E( Metal Loss Body Page 3 I. PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE-8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lD-125A Kuparu k CONOCOPHILLlPS ALASKA, INC USA July 31,2005 Joint Jt. Depth Pen. Pen. Pen. Melal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) (10 (Ins.) 0 50 100 140.3 4518 0 0.10 38 7 2.85 PUP Corrosion. Lt. Deposits. ~ 140.4 4528 0 0 0 0 2.78 PACKER 140.5 4533 0 0.07 27 " 2.82 PUP Corrosion. . ) 141 4538 0.07 0.09 36 6 2.88 Line corrosion. 142 4569 0 0.02 8 3 2.87 . Penetration Body I.'.. Metal Loss Body Page 4 cIds., PDS Report Cross Sections Well: Field: Company: Country: Tubing: lD-125A Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 74 at depth 2343.77 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 60 0 Finger 10 Penetration = 0.121 ins Line Corrosion 0.12 ins = 48% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ..lw->6. ~ R' Well: Field: Company: Country: Tubing: PDS Report Cross Sections lD-125A Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No 99628 1.69 24 }. Thompson Cross Section for Joint 138.1 at depth 4399.84 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 31 0 Finger 17 Penetration = 0.12 ins Line Corrosion 0.12 ins = 47% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .1 ->. ~~-. .. . ... is ~ ~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: lD-125A Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No 99628 1.69 24 j. Thompson Cross Section for Joint 57 at depth 1805.2 ft Tool speed = 50 Nominal to = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 59 0 Finger 8 Projection = -0.066 ins Deposits Min 10 = 2.70 ins HIGH SIDE = UP Cross Sections page 3 ..I~---'.· .'. 'lS ~ ~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: lD-125A Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 78 at depth 2499.37 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 60 0 ~- Finger 5 Projection = -0.049 ins Deposits Min 10 = 2.70 ins. HIGH SIDE = UP Cross Sections page 4 ~PHILLIPS Alal.~a, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING 1D-125A (0-4529, OD:3.500, ID:2.992) PRODUCTION (0-4719, OD:5.500, Wt:15.(0) D NIP (4459-4460, OD:3.500) I PBR (4505-4506, OD:4.795) I I LINER (4529-5636, OD:3.500, Wt:9.30) I Perf (5096-5130) Perf (5160-5194) Perf (5210-5234) Perf (5252-5260) Perf (5270-5288) Perf (5298-5304) Perf (5324-5338) Perf (5350-5365) Perf (5375-5384) Perf (5396-5410) TVD Wt Grade Thread 121 62,58 H-40 WELDED 3201 15.00 L-80 BTCM 4049 9,30 L-80 EUE 8RD Wt Grade Thread 9.30 L-80 EUE 8RD K\_J API: 500292290401 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: 5470 Last Tag Date: 7/201200 1 Casing String - ALL Description CONDUCTOR PRODUCTION LINER Tubing String - ALL Size I Top 3.500 0 Perforations Summary Interval TVD 5096 - 5130 3552 - 3584 5160 - 5194 3611 - 3643 521 0 - 5234 3658 - 3680 5252 - 5260 3696 - 3704 5270 - 5288 3713 - 3729 5298 - 5304 3738 - 3744 5324 - 5338 3762 - 3775 5350 - 5365 3786 - 3800 5375 - 5384 3809 - 3817 5396 - 5410 3828 - 3841 Gas Lift MandrelsNalves st MD lVD Man Man Mfr Type 1 4400 2933 CAMCO KBG29 CAMCO DMY Other ~Jlugsl equip., etc.) - JEWELRY Depth TVD Type 4459 2981 NIP CAMCO OS NIPPLE 4505 3019 PBR BAKER 80-40 WITH 10' SEALS 4530 3039 PKR BAKER SABL-3 PACKER Well Type: INJ Orig Completion: 4/11/2000 Last W/O: Ref Log Date: TO: 5639 ftKB Max Hole Angle: 65 deg @ 2967 Size 16.000 5.500 3.500 Top o o 4529 Bottom 121 4719 5636 I Bottom 4529 TVD 3039 Zone WSD WSB WSA4 WSA3 WSA3 WSA3 WSA2 WSA2 WSA2 WSA2 Status Ft SPF Date 34 4 5/30/2000 34 4 5/3012000 24 4 5/30/2000 8 4 5130/2000 18 4 5/30/2000 6 4 5130/2000 14 4 5130/2000 15 4 5/30/2000 9 4 5/29/2000 14 4 5/29/2000 VMfr 1 D-125A Angle @ TS: deg @ Angle <.œ. TO: 23 deg <.œ. 5639 Rev Reason: Tag by ImO Last Update: 81212001 Type IPERF (PERF IPERF IPERF IPERF IPERF IPERF IPERF IPERF IPERF Comment 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2,5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 180 DEG PH, 2.5" HC DP 1.0 V Type V OD Latch Port TRO o Description INT 0.000 Date Run 4/11/2000 Vlv Cmnt ID 2.812 2.985 2.780 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jan 30 11:43:42 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/01/30 Origin ................... STS Tape Name ................. UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparak River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MW-00016 ADAM WEAVER DON WEBSTER 1D-125A 500292290401 Arco Alaska, Inc. Sperry Sun 30-JAN-01 23 liN 10E 286 599 100.48 DERRICK FLOOR: 100.48 GROUND LEVEL: 70.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 4689.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MEULLER TUBE DETECTORS. 4. MWD DATA IS TIED INTO THE MWD GAMMA RAY FROM 1D-125 (SPERRY-SUN) AND IS PDC. 5. THIS WELL KICKS OFF FROM 1D-125 AT 4689' MD, 3175' TVD. 6. MWD RUN 2 REPRESENTS WELL 1D-125A WITH API# 50-029-22904-01. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4683.0 5604.5 ROP 4714.0 5638.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 4683.0 5638.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 4683 5638.5 5160.75 1912 ROP MWD FT/H 0 659.66 118.402 1850 GR MWD API 23.2 140.21 86.4628 1844 First Reading 4683 4714 4683 Last Reading 5638.5 5638.5 5604.5 First Reading For Entire File .......... 4683 Last Reading For Entire File ........... 5638.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/30 Maximum Physical Record.,.65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4683.0 ROP 4714.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5604.5 5638.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 09-APR-00 Insite 0.43 Memory 5639.0 18.1 30.0 TOOL NUMBER 74169 4.750 4689.0 Water Based 9.20 62.0 8.7 1200 6.5 .000 .000 .000 .000 .0 84.2 .0 .0 Tape Trailer Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/01/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Physical EOF File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/01/30 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.003 First Reading For Entire File......... .4683 Last Reading For Entire File.......... .5638.5 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4683 5638.5 5160.75 1912 4683 5638.5 ROP MWD020 FT/H 0 659.66 118.402 1850 4714 5638.5 GR MWD020 API 23.2 140.21 86.4628 1844 4683 5604.5 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Order DEPT ROP MWD020 GR MWD020 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O $ REMARKS: # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # MATRIX DENSITY: HOLE CORRECTION (IN) ,.-, Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/01/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
